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Home My WebLink About168-091From:McLellan, Bryan J (OGC) To:Chad Helgeson Cc:Donna Ambruz Subject:RE: [EXTERNAL] RE: NCIU A-02 (PTD #168-091) Sundry #322-102 Date:Thursday, May 5, 2022 2:59:00 PM Chad, The AOGCC will accept the pre-production MITIA on this well in place of the witnessed test based on your information below and the acceptable chart. Thank you. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Wednesday, May 4, 2022 1:06 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: RE: [EXTERNAL] RE: NCIU A-02 (PTD #168-091) Sundry #322-102 Bryan, Please see attached, current Tyonek A-02 schematic. Chad From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, May 4, 2022 8:43 AM To: Chad Helgeson <chelgeson@hilcorp.com> Subject: [EXTERNAL] RE: NCIU A-02 (PTD #168-091) Sundry #322-102 Chad, can you send me the current wellbore schematic? Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Tuesday, May 3, 2022 4:04 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: NCIU A-02 (PTD #168-091) Sundry #322-102 Bryan, This is the follow-up to our discussion from 2 weeks ago about step 9 in the approved sundry for an MIT-IA of Tyonek A-2 well. On this well we gave notice to AOGCC to witness the MIT-IA listed in step 9 and the response was that it would be witnessed on one of the other visits for BOP test or MIT-IA requests on the other wells. This well was different as it was a producer where we unloaded the well with gas lift and it is not a plugged well like the other workover we completed at the same time on the Tyonek platform. We didn’t get the waived witnessed approval, but we did complete a charted MIT-IA (attached). Does this charted test meet the requirements for step 9 or would the state like us to fill the annulus with fluid (currently filled with methane) and complete a witnessed MIT-IA? Please let me know if you have any questions on this. Chad Helgeson KEN Operations Engineer Hilcorp Alaska LLC chelgeson@hilcorp.com 907-777-8405 (O) 907-229-4824 (C) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. From:McLellan, Bryan J (OGC) To:Chad Helgeson Cc:Aras Worthington; Donna Ambruz; Dan Marlowe; Regg, James B (OGC) Subject:RE: [EXTERNAL] RE: NCIU A-02 (PTD# 168-091) Sundry # 322-102 Date:Thursday, April 14, 2022 3:08:00 PM Chad, Hilcorp’s request for a variance to 20AAC25.265(C)(1) is approved, to install the SSV in the horizontal run of the tree in well NCIU A-02. This is the most common practice in the Cook Inlet and there is benefit in having a consistent design in the region. If Hilcorp plans to make this request for multiple other wells on Tyonek platform, please submit a request with justification for doing so. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Tuesday, April 12, 2022 12:51 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Aras Worthington <Aras.Worthington@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com> Subject: RE: [EXTERNAL] RE: NCIU A-02 (PTD# 168-091) Sundry # 322-102 Bryan, When you look at the original design of the Tyonek Wells, there are 3 automated valves on the wells, the subsurface safety valve, a safety valve in the vertical run of the tree and one on the horizontal run of the tree. They are all tied into the SVS system and trip on the same occurrences. We do not believe 3 safety valves are necessary for these wells that flow at very low pressures. Our new well design removes the automated valve in the Vertical run above the Master valve, and is replaced with a manual valve to be consistent with most of our wells in the inlet. The drawings of both trees are included in the original approved sundry 322-102. When evaluating if we need 3 or 2 safety valves for these trees, the valve we determined has the most risk to impacting our operations is the automated valve in the vertical run of the tree. The additional risk of the vertical valve is that wellwork requires the valve to be mechanically locked open. The advantage of the horizontal safety valve is that it provides the opportunity to leave the SSV functional while performing well work. There’s also a consistency and standardization component that would align these wells trees with all of our others onshore and offshore. This consistency can help mitigate complications during wellwork from our wireline vendors, and reduce the risk of dropped tools from a valve not being locked open. If the surface safety valve needs servicing or replacement, having the valve in the horizontal run is safer. The risk the wells on the Tyonek currently is much less than when it was originally designed and built. The A-02 well currently flows at 90 psi and 4 mmscfd and builds up to 220 psi when shut-in, which is much different than what the original design and well flowing conditions which were flowing at rates up to 20mmscfd at pressures at 1900 psi. Please let me know if you would like to discuss any of these details. Chad From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, April 11, 2022 12:45 PM To: Chad Helgeson <chelgeson@hilcorp.com> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: RE: [EXTERNAL] RE: NCIU A-02 (PTD# 168-091) Sundry # 322-102 Chad, What is the motivation for putting it in the horizontal position on A-02? We can handle it by email, but need some supporting evidence as mentioned below. Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Monday, April 11, 2022 12:30 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: RE: [EXTERNAL] RE: NCIU A-02 (PTD# 168-091) Sundry # 322-102 Bryan, I can do that. How should we handle A-02 since we will be bringing it back online on Wednesday with a SSSV in horizontal run? Is my email below enough to ask for variance for A-02, or would you like to see some additional paperwork on it? Chad From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, April 11, 2022 12:21 PM To: Chad Helgeson <chelgeson@hilcorp.com> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: RE: [EXTERNAL] RE: NCIU A-02 (PTD# 168-091) Sundry # 322-102 Chad, Recommend that you write a justification request for the wells on the Tyonek if you want the ability to place all the SSVs in the horizontal run. Questions to address in the letter: What is the motivation/benefit for changing the tree design on Tyonek platform and what risks does it present? How is it equal to or better than having a SSV in the vertical run? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Monday, April 11, 2022 9:57 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: RE: [EXTERNAL] RE: NCIU A-02 (PTD# 168-091) Sundry # 322-102 Bryan Attached are the ones we received from all Chevron & Marathon operated fields and Beluga River. I am not sure why this wasn’t requested for on the Tyonek platform. Last year we included these in the 10-403 completion sundries and you approved them on the 3 drill wells we had last year. We can do that again, but we will drill 5 more wells this year and 5 more next year probably. Chad From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Sent: Monday, April 11, 2022 9:09 AM To: Chad Helgeson <chelgeson@hilcorp.com> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: [EXTERNAL] RE: NCIU A-02 (PTD# 168-091) Sundry # 322-102 Chad, Could you send me the blanket approval from 2011? I have only heard about it, but haven’t seen if it is conditional or if there are some criteria that must be met before moving to the horizontal. Thank you Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Monday, April 11, 2022 6:55 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: NCIU A-02 (PTD# 168-091) Sundry # 322-102 Bryan, We are moving forward with A-02 nicely, pulling the old completion currently. I forgot to include in my sundry a variance request for the SSV in the vertical run in the well. What is the best way to handle this request? Can it be done with an email, like this, or do you need a new 10-403 submitted for it. Request: Hilcorp requests a waiver to 20AAC25.265(C)(1). We request a variance to regulations to locate the SSV on the tree wing in the horizontal run of piping allowing the SSV to remain in the production stream while providing concurrent wellbore access. Also on all our new drill wells, we will be asking for this same waiver. Would it be easier to write them individually or should we write an application request for all well on the Tyonek Platform, similar to what was done in 2011 when the change was made to the regulations? Chad Helgeson KEN Operations Engineer Hilcorp Alaska LLC chelgeson@hilcorp.com 907-777-8405 (O) 907-229-4824 (C) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. From:McLellan, Bryan J (OGC) To:Chad Helgeson Subject:Re: [EXTERNAL] RE: NCIU A-02 (PTD# 168-091) Sundry # 322-102 Date:Wednesday, April 13, 2022 8:34:33 PM Chad, Approval granted to proceed with your plan below. Bryan Sent from my iPhone On Apr 13, 2022, at 6:47 PM, Chad Helgeson <chelgeson@hilcorp.com> wrote: Yes the hole is all in the same pool. We will test the seals before we set the packer to make sure we don’t have communication with the hole. Chad Sent from my iPhone On Apr 13, 2022, at 5:54 PM, McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> wrote: Disregard question #2. I see you are planning to straddle it between two sealing packers. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: McLellan, Bryan J (OGC) Sent: Wednesday, April 13, 2022 5:52 PM To: Chad Helgeson <chelgeson@hilcorp.com> Subject: RE: NCIU A-02 (PTD# 168-091) Sundry # 322-102 Chad, CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. This shouldn’t be a problem since it is so close to the existing packer and perfs and you have top of cement above that point. A couple questions: 1. Is the hole in the casing in the same pool as the perfs below it? 2. Will the hole in the casing be open to the tubing, able to flow, or will it be straddled between two sealing packers? Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Wednesday, April 13, 2022 4:33 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Harold Soule - (C) <hsoule@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com> Subject: NCIU A-02 (PTD# 168-091) Sundry # 322-102 Bryan, We ran our completion on the Tyonek A-02 well last night and were not able to pass our MIT-IA, It held flat for almost a minute and then started dropping. The tubing tested good. See attached photos of tests prior to the testing we did today. Summary of events: -Pulled the completion out and ran in today with a test packer and find the leak. -Set the packer 28ft above the existing packer (~4,353’) and tested below (tubing and packer @ 4,831’) and it passed the test. -Tested above 4,353 and it did not pass -Moved the packer up to 4,276 and the casing test passed to 1,500 psi. - The tubing below the packer did not pass the test. This is indicating that the leak is between 4,353 and 4,276. (It is possible the leak is from the tubing punch, as casing tested before we pulled completion and held for a little bit and then broke over) We are requesting approval to set another permanent packer above the leak at ~4,275’ and set the tubing in the seals and straddling this leak with the 2 packers as shown on the attached schematic. The TOC is listed in original drilling files at 3,900’ based on a CBL run in ’68, but I couldn’t find that file in our documents anywhere. We plan to be running this new completion tonight, and setting the packer in the morning. Call, text or email me any questions. Chad Helgeson KEN Operations Engineer Hilcorp Alaska LLC chelgeson@hilcorp.com 907-777-8405 (O) 907-229-4824 (C) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, thenpromptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only forthe use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out suchvirus and other checks as it considers appropriate. ____________________________________________________________________________________ Updated By: CAH 4/13/2022 PROPOSED-2 North Cook Inlet Well: NCI A-02 Last Completed: 07/01/1994 PTD: 168-091 API: 50-883-20018-00-00 CASING DETAIL Size Wt Grade Conn ID Top Btm 30” Conductor 29.00 Surf 385’ 16” 65 H-40 15.250 Surf 621’ 10-3/4” 45.5 J-55 BT&C 9.950 Surf 465’ 51 J-55 BT&C 9.850 465’ 2,634’ 7” 26 J-55 BT&C 6.276 Surf 80’ 23 J-55 BT&C 6.366 80’ 6,659’ 26 J-55 BT&C 6.276 6,659’ 7,189’ TUBING DETAIL 4-1/2” 12.60 L-80 Mod BT&C 3.958 Surf ~4,371’ 4-1/2” 12.75 J-55 Mod EUE 8RD 3.958 ~4,371’ 6,626’ JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item 40.2’ 40.2’ Cactus-EN-CCL 5M 4-1/16 Tubing Hanger 1 ~350’ ~350’ 3.812 5.250 Baker ONYX-R5E TRSSSV 2 ~1,900 ~1,831’ 3.865 6.059 Gas Lift Mandrel 2A ~4,240’ ~3,756’ 3.813 5.560 Sliding Sleeve 2B ~4,275’ ~3,783’ 4.00 5.875 Hydraulic Permanent packer D&L Oil Tools PN 68571 2C ~4,310 3.813 5.50 X landing nipple 3 ~4,371’ ~3,858’ 3.813 5.750 Halliburton Upper “PBR” Assembly 4,380’ 3,865’ 3.990 5.560 Ratch Latch Seal Unit 4,381’ 3,866’ 3.880 5.830 Halliburton “VSR” Packer 4 4,419’ 3,896’ 3.813 5.560 Halliburton X Landing Nipple 5 4,539’ 3,989’ 3.813 5.560 Halliburton XD Sliding Sleeve - Closed 6 4,548’ 3,996’ 3.990 5.560 No Go Seal Unit 7 4,549’ 3,997’ 4.000 5.830 Halliburton “AWR” Packer & Millout Extension 8 4,637’ 4,066’ 3.813 5.560 Halliburton XD Sliding Sleeve - Closed 9 4,645’ 4,072’ 3.990 5.560 No Go Seal Unit 10 4,647’ 4,074’ 4.000 5.830 Halliburton “AWR” Packer & Millout Extension 11 4,704’ 4,118’ 3.813 5.560 Halliburton XD Sliding Sleeve - Closed 12 4,738’ 4,144’ 3.990 5.560 No Go Seal Unit 13 4,740’ 4,146’ 4.000 5.830 Halliburton “AWR” Packer & Millout Extension 14 4,992’ 4,341’ 3.990 5.560 No Go Seal Unit 15 4,993’ 4,342’ 4.000 5.830 Halliburton “AWR” Packer & Millout Extension 16 5,064’ 4,397’ 3.813 5.560 Halliburton XD Sliding Sleeve - Open 17 5,099’ 4,425’ 3.990 5.560 No Go Seal Unit 18 5,101’ 4,426’ 4.000 5.830 Halliburton “AWR” Packer & Millout Extension 19 5,383’ 4,654’ 3.990 5.560 No Go Seal Unit 20 5,384’ 4,655’ 4.000 5.830 Halliburton “AWR” Packer & Millout Extension 21 5,550’ 4,791’ 3.813 5.560 Halliburton XA Sliding Sleeve - Open 22 6,624’ 5,684’ 3.725 4.970 Halliburton XN Nipple 23 6 625’ 5 685’ 4 000 5 561 Wi li R Et Gid Notes: 12/10/1968 – 7” casing cmt: Stage 1: 428 sacks of 14.7 ppg with good circ Stage 2: 620 sacks of 15.1 ppg with good returns, no cement to Surface Drill reports say CBL TOC is 3,900’ 1/11/69 – Isolation Sleeve Patch – 4,539’ 1/11/69 – Isolation Sleeve Patch – 5,063’ 1/21/15 – Sand in tubing - 6,000’ 7/17/11 – Fill covering Perfs below - 6,029’ 6/19/19 - LIB of parted tubing – 5,263’ 4/13/22 – During RWO found leak in casing between 4,381-4,276’ ____________________________________________________________________________________ Updated By: CAH 04/13/2022 PROPOSED-2 North Cook Inlet Well: NCI A-02 Last Completed: 07/01/1994 PTD: 168-091 API: 50-883-20018-00-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Status CI-1.0 4,445' 4,535' 3,916' 3,986' 90' Closed CI-2.0 4,554' 4,630' 4,001' 4,060' 76' Closed CI-3.0 4,656' 4,670' 4,081' 4,091' 14' Closed CI-5.0 4,800' 4,821' 4,192' 4,208' 21' Closed CI-6.0 4,886' 4,904' 4,259' 4,273' 18' Closed CI-8.0 5,047' 5,059' 4,384' 4,393' 12' Open CI-9.0 5,120' 5,142' 4,441' 4,459' 22' Open CI-11.0 5,238' 5,252' 4,536' 4,547' 14' Open B-6 5,504' 5,510' 4,753' 4,758' 6' Open B-7 5,522' 5,527' 4,768' 4,772' 5' Open C-2 5,628' 5,632' 4,854' 4,858' 4' Open C-3 5,676' 5,680' 4,894' 4,897' 4' Open C-4 5,702' 5,708' 4,915' 4,920' 6' Open C-5 5,715' 5,730' 4,925' 4,938' 15' Open D-3 5,798' 5,808' 4,993' 5,001' 10' Open D-4 5,855' 5,862' 5,039' 5,045' 7' Open D-5 5,879' 5,888' 5,059' 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ϴϰ͕ϲϯϳ͛ϰ͕Ϭϲϲ͛ϯ͘ϴϭϯϱ͘ϱϲϬ,ĂůůŝďƵƌƚŽŶy^ůŝĚŝŶŐ^ůĞĞǀĞͲůŽƐĞĚ ϵϰ͕ϲϰϱ͛ϰ͕ϬϳϮ͛ϯ͘ϵϵϬϱ͘ϱϲϬEŽ'Ž^ĞĂůhŶŝƚ ϭϬϰ͕ϲϰϳ͛ϰ͕Ϭϳϰ͛ϰ͘ϬϬϬϱ͘ϴϯϬ,ĂůůŝďƵƌƚŽŶ͞tZ͟WĂĐŬĞƌΘDŝůůŽƵƚǆƚĞŶƐŝŽŶ ϭϭϰ͕ϳϬϰ͛ϰ͕ϭϭϴ͛ϯ͘ϴϭϯϱ͘ϱϲϬ,ĂůůŝďƵƌƚŽŶy^ůŝĚŝŶŐ^ůĞĞǀĞͲůŽƐĞĚ ϭϮϰ͕ϳϯϴ͛ϰ͕ϭϰϰ͛ϯ͘ϵϵϬϱ͘ϱϲϬEŽ'Ž^ĞĂůhŶŝƚ ϭϯϰ͕ϳϰϬ͛ϰ͕ϭϰϲ͛ϰ͘ϬϬϬϱ͘ϴϯϬ,ĂůůŝďƵƌƚŽŶ͞tZ͟WĂĐŬĞƌΘDŝůůŽƵƚǆƚĞŶƐŝŽŶ ϭϰϰ͕ϵϵϮ͛ϰ͕ϯϰϭ͛ϯ͘ϵϵϬϱ͘ϱϲϬEŽ'Ž^ĞĂůhŶŝƚ ϭϱϰ͕ϵϵϯ͛ϰ͕ϯϰϮ͛ϰ͘ϬϬϬϱ͘ϴϯϬ,ĂůůŝďƵƌƚŽŶ͞tZ͟WĂĐŬĞƌΘDŝůůŽƵƚǆƚĞŶƐŝŽŶ ϭϲϱ͕Ϭϲϰ͛ϰ͕ϯϵϳ͛ϯ͘ϴϭϯϱ͘ϱϲϬ,ĂůůŝďƵƌƚŽŶy^ůŝĚŝŶŐ^ůĞĞǀĞͲKƉĞŶ ϭϳϱ͕Ϭϵϵ͛ϰ͕ϰϮϱ͛ϯ͘ϵϵϬϱ͘ϱϲϬEŽ'Ž^ĞĂůhŶŝƚ ϭϴϱ͕ϭϬϭ͛ϰ͕ϰϮϲ͛ϰ͘ϬϬϬϱ͘ϴϯϬ,ĂůůŝďƵƌƚŽŶ͞tZ͟WĂĐŬĞƌΘDŝůůŽƵƚǆƚĞŶƐŝŽŶ ϭϵϱ͕ϯϴϯ͛ϰ͕ϲϱϰ͛ϯ͘ϵϵϬϱ͘ϱϲϬEŽ'Ž^ĞĂůhŶŝƚ ϮϬϱ͕ϯϴϰ͛ϰ͕ϲϱϱ͛ϰ͘ϬϬϬϱ͘ϴϯϬ,ĂůůŝďƵƌƚŽŶ͞tZ͟WĂĐŬĞƌΘDŝůůŽƵƚǆƚĞŶƐŝŽŶ Ϯϭϱ͕ϱϱϬ͛ϰ͕ϳϵϭ͛ϯ͘ϴϭϯϱ͘ϱϲϬ,ĂůůŝďƵƌƚŽŶy^ůŝĚŝŶŐ^ůĞĞǀĞͲKƉĞŶ ϮϮϲ͕ϲϮϰ͛ϱ͕ϲϴϰ͛ϯ͘ϳϮϱϰ͘ϵϳϬ,ĂůůŝďƵƌƚŽŶyEEŝƉƉůĞ Ϯϯϲ͕ϲϮϱ͛ϱ͕ϲϴϱ͛ϰ͘ϬϬϬϱ͘ϱϲϭtŝƌĞůŝŶĞZĞͲŶƚƌǇ'ƵŝĚĞ EŽƚĞƐ͗ ϭͬϭϭͬϲϵʹ/ƐŽůĂƚŝŽŶ^ůĞĞǀĞWĂƚĐŚʹϰ͕ϱϯϵ͛ ϭͬϭϭͬϲϵʹ/ƐŽůĂƚŝŽŶ^ůĞĞǀĞWĂƚĐŚʹϱ͕Ϭϲϯ͛ ϭͬϮϭͬϭϱʹ^ĂŶĚŝŶƚƵďŝŶŐĂƚϲ͕ϬϬϬ͛ ϳͬϭϳͬϭϭʹ&ŝůůĐŽǀĞƌŝŶŐWĞƌĨƐďĞůŽǁϲ͕ϬϮϵ͛ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚǇ͗:>>ϬϲͬϮϭͬϮϬϭϵ ^,Dd/ EŽƌƚŚŽŽŬ/ŶůĞƚ tĞůů͗E/ͲϬϮ >ĂƐƚŽŵƉůĞƚĞĚ͗ϬϳͬϬϭͬϭϵϵϰ Wd͗ϭϲϴͲϬϵϭ W/͗ϱϬͲϴϴϯͲϮϬϬϭϴͲϬϬͲϬϬ WZ&KZd/KEd/> ŽŶĞdŽƉ;DͿƚŵ;DͿdŽƉ;dsͿƚŵ;dsͿ&d^ƚĂƚƵƐ /Ͳϭ͘Ϭ ϰ͕ϰϰϱΖ ϰ͕ϱϯϱΖ ϯ͕ϵϭϲΖ ϯ͕ϵϴϲΖ ϵϬΖ ůŽƐĞĚ /ͲϮ͘Ϭ ϰ͕ϱϱϰΖ ϰ͕ϲϯϬΖ ϰ͕ϬϬϭΖ ϰ͕ϬϲϬΖ ϳϲΖ ůŽƐĞĚ /Ͳϯ͘Ϭϰ͕ϲϱϲΖϰ͕ϲϳϬΖϰ͕ϬϴϭΖϰ͕ϬϵϭΖϭϰΖůŽƐĞĚ /Ͳϱ͘Ϭ ϰ͕ϴϬϬΖ ϰ͕ϴϮϭΖ ϰ͕ϭϵϮΖ ϰ͕ϮϬϴΖ ϮϭΖ ůŽƐĞĚ /Ͳϲ͘Ϭϰ͕ϴϴϲΖϰ͕ϵϬϰΖϰ͕ϮϱϵΖϰ͕ϮϳϯΖϭϴΖůŽƐĞĚ /Ͳϴ͘Ϭ ϱ͕ϬϰϳΖ ϱ͕ϬϱϵΖ ϰ͕ϯϴϰΖ ϰ͕ϯϵϯΖ ϭϮΖ KƉĞŶ /Ͳϵ͘Ϭϱ͕ϭϮϬΖϱ͕ϭϰϮΖϰ͕ϰϰϭΖϰ͕ϰϱϵΖϮϮΖKƉĞŶ /Ͳϭϭ͘Ϭϱ͕ϮϯϴΖ ϱ͕ϮϱϮΖ ϰ͕ϱϯϲΖ ϰ͕ϱϰϳΖ ϭϰΖ KƉĞŶ Ͳϲ ϱ͕ϱϬϰΖ ϱ͕ϱϭϬΖ ϰ͕ϳϱϯΖ ϰ͕ϳϱϴΖ ϲΖ KƉĞŶ Ͳϳϱ͕ϱϮϮΖϱ͕ϱϮϳΖϰ͕ϳϲϴΖϰ͕ϳϳϮΖϱΖKƉĞŶ ͲϮ ϱ͕ϲϮϴΖ ϱ͕ϲϯϮΖ ϰ͕ϴϱϰΖ ϰ͕ϴϱϴΖ ϰΖ KƉĞŶ Ͳϯϱ͕ϲϳϲΖϱ͕ϲϴϬΖϰ͕ϴϵϰΖϰ͕ϴϵϳΖϰΖKƉĞŶ Ͳϰ ϱ͕ϳϬϮΖ ϱ͕ϳϬϴΖ ϰ͕ϵϭϱΖ ϰ͕ϵϮϬΖ ϲΖ KƉĞŶ Ͳϱ ϱ͕ϳϭϱΖ ϱ͕ϳϯϬΖ ϰ͕ϵϮϱΖ ϰ͕ϵϯϴΖ ϭϱΖ KƉĞŶ Ͳϯϱ͕ϳϵϴΖϱ͕ϴϬϴΖϰ͕ϵϵϯΖϱ͕ϬϬϭΖϭϬΖKƉĞŶ Ͳϰ ϱ͕ϴϱϱΖ ϱ͕ϴϲϮΖ ϱ͕ϬϯϵΖ ϱ͕ϬϰϱΖ ϳΖ KƉĞŶ Ͳϱϱ͕ϴϳϵΖϱ͕ϴϴϴΖϱ͕ϬϱϵΖϱ͕ϬϲϲΖϵΖKƉĞŶ Ͳϰ ϱ͕ϵϰϬΖ ϱ͕ϵϰϱΖ ϱ͕ϭϬϵΖ ϱ͕ϭϭϯΖ ϱΖ KƉĞŶ Ͳϴϲ͕ϬϬϮΖϲ͕ϬϭϭΖϱ͕ϭϱϵΖϱ͕ϭϲϲΖϵΖKƉĞŶ &Ͳϯ ϲ͕ϬϴϮΖ ϲ͕ϬϵϬΖ ϱ͕ϮϮϱΖ ϱ͕ϮϯϮΖ ϴΖ KƉĞŶ &Ͳϲ ϲ͕ϭϰϬΖ ϲ͕ϭϰϴΖ ϱ͕ϮϳϯΖ ϱ͕ϮϴϬΖ ϴΖ KƉĞŶ 'Ͳϭϲ͕ϭϳϲΖϲ͕ϮϬϯΖϱ͕ϯϬϯΖϱ͕ϯϮϲΖϮϳΖKƉĞŶ 'Ͳϱ ϲ͕ϮϲϬΖ ϲ͕ϮϴϲΖ ϱ͕ϯϳϯΖ ϱ͕ϯϵϱΖ ϮϲΖ KƉĞŶ ,Ͳϴϲ͕ϰϭϮΖϲ͕ϰϯϬΖϱ͕ϱϬϮΖϱ͕ϱϭϳΖϭϴΖKƉĞŶ :ͲϮ ϲ͕ϲϬϮΖ ϲ͕ϲϭϮΖ ϱ͕ϲϲϱΖ ϱ͕ϲϳϰΖ ϭϬΖ KƉĞŶ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚǇ͗,ϯͬϯͬϮϬϮϮ WZKWK^ EŽƌƚŚŽŽŬ/ŶůĞƚ tĞůů͗E/ͲϬϮ >ĂƐƚŽŵƉůĞƚĞĚ͗ϬϳͬϬϭͬϭϵϵϰ Wd͗ϭϲϴͲϬϵϭ W/͗ϱϬͲϴϴϯͲϮϬϬϭϴͲϬϬͲϬϬ ^/E'd/> ^ŝǌĞtƚ'ƌĂĚĞŽŶŶ/dŽƉƚŵ ϯϬ͟ŽŶĚƵĐƚŽƌϮϵ͘ϬϬ^ƵƌĨϯϴϱ͛ ϭϲ͟ϲϱ,ͲϰϬϭϱ͘ϮϱϬ^ƵƌĨϲϮϭ͛ ϭϬͲϯͬϰ͟ϰϱ͘ϱ:ͲϱϱdΘϵ͘ϵϱϬ^ƵƌĨϰϲϱ͛ ϱϭ:ͲϱϱdΘϵ͘ϴϱϬϰϲϱ͛Ϯ͕ϲϯϰ͛ ϳ͟ Ϯϲ:ͲϱϱdΘϲ͘Ϯϳϲ^ƵƌĨϴϬ͛ Ϯϯ:ͲϱϱdΘϲ͘ϯϲϲϴϬ͛ϲ͕ϲϱϵ͛ Ϯϲ:ͲϱϱdΘϲ͘Ϯϳϲϲ͕ϲϱϵ͛ϳ͕ϭϴϵ͛ dh/E'd/> ϰͲϭͬϮ͟ ϭϮ͘ϲϬ >ͲϴϬ DŽĚ dΘϯ͘ϵϱϴ ^ƵƌĨΕϰ͕ϯϳϭ͛ ϰͲϭͬϮ͟ ϭϮ͘ϳϱ :Ͳϱϱ DŽĚh ϴZϯ͘ϵϱϴΕϰ͕ϯϳϭ͛ϲ͕ϲϮϲ͛ :t>Zzd/> EŽĞƉƚŚ ;DͿ ĞƉƚŚ ;dsͿ/K/ƚĞŵ ϰϬ͘Ϯ͛ϰϬ͘Ϯ͛ĂĐƚƵƐͲEͲ>ϱDϰͲϭͬϭϲdƵďŝŶŐ,ĂŶŐĞƌ ϭΕϯϱϬ͛ΕϯϱϬϯ͘ϴϭϮϱ͘ϮϱϬĂŬĞƌKEzyͲZϱdZ^^^s ϮΕϰ͕ϯϬϬΕϯ͕ϴϬϯϯ͘ϴϲϱϲ͘Ϭϱϵ'ĂƐ>ŝĨƚDĂŶĚƌĞů ϯ Εϰ͕ϯϳϭ͛Εϯ͕ϴϱϴ͛ϯ͘ϴϭϯϱ͘ϳϱϬ,ĂůůŝďƵƌƚŽŶhƉƉĞƌ͞WZ͟ƐƐĞŵďůǇ ϰ͕ϯϴϬ͛ϯ͕ϴϲϱ͛ϯ͘ϵϵϬϱ͘ϱϲϬZĂƚĐŚ>ĂƚĐŚ^ĞĂůhŶŝƚ ϰ͕ϯϴϭ͛ϯ͕ϴϲϲ͛ϯ͘ϴϴϬϱ͘ϴϯϬ,ĂůůŝďƵƌƚŽŶ͞s^Z͟WĂĐŬĞƌ ϰϰ͕ϰϭϵ͛ϯ͕ϴϵϲ͛ϯ͘ϴϭϯϱ͘ϱϲϬ,ĂůůŝďƵƌƚŽŶy>ĂŶĚŝŶŐEŝƉƉůĞ ϱϰ͕ϱϯϵ͛ϯ͕ϵϴϵ͛ϯ͘ϴϭϯϱ͘ϱϲϬ,ĂůůŝďƵƌƚŽŶy^ůŝĚŝŶŐ^ůĞĞǀĞͲůŽƐĞĚ ϲϰ͕ϱϰϴ͛ϯ͕ϵϵϲ͛ϯ͘ϵϵϬϱ͘ϱϲϬEŽ'Ž^ĞĂůhŶŝƚ ϳϰ͕ϱϰϵ͛ϯ͕ϵϵϳ͛ϰ͘ϬϬϬϱ͘ϴϯϬ,ĂůůŝďƵƌƚŽŶ͞tZ͟WĂĐŬĞƌΘDŝůůŽƵƚǆƚĞŶƐŝŽŶ ϴϰ͕ϲϯϳ͛ϰ͕Ϭϲϲ͛ϯ͘ϴϭϯϱ͘ϱϲϬ,ĂůůŝďƵƌƚŽŶy^ůŝĚŝŶŐ^ůĞĞǀĞͲůŽƐĞĚ ϵϰ͕ϲϰϱ͛ϰ͕ϬϳϮ͛ϯ͘ϵϵϬϱ͘ϱϲϬEŽ'Ž^ĞĂůhŶŝƚ ϭϬϰ͕ϲϰϳ͛ϰ͕Ϭϳϰ͛ϰ͘ϬϬϬϱ͘ϴϯϬ,ĂůůŝďƵƌƚŽŶ͞tZ͟WĂĐŬĞƌΘDŝůůŽƵƚǆƚĞŶƐŝŽŶ ϭϭϰ͕ϳϬϰ͛ϰ͕ϭϭϴ͛ϯ͘ϴϭϯϱ͘ϱϲϬ,ĂůůŝďƵƌƚŽŶy^ůŝĚŝŶŐ^ůĞĞǀĞͲůŽƐĞĚ ϭϮϰ͕ϳϯϴ͛ϰ͕ϭϰϰ͛ϯ͘ϵϵϬϱ͘ϱϲϬEŽ'Ž^ĞĂůhŶŝƚ ϭϯϰ͕ϳϰϬ͛ϰ͕ϭϰϲ͛ϰ͘ϬϬϬϱ͘ϴϯϬ,ĂůůŝďƵƌƚŽŶ͞tZ͟WĂĐŬĞƌΘDŝůůŽƵƚǆƚĞŶƐŝŽŶ ϭϰϰ͕ϵϵϮ͛ϰ͕ϯϰϭ͛ϯ͘ϵϵϬϱ͘ϱϲϬEŽ'Ž^ĞĂůhŶŝƚ ϭϱϰ͕ϵϵϯ͛ϰ͕ϯϰϮ͛ϰ͘ϬϬϬϱ͘ϴϯϬ,ĂůůŝďƵƌƚŽŶ͞tZ͟WĂĐŬĞƌΘDŝůůŽƵƚǆƚĞŶƐŝŽŶ ϭϲϱ͕Ϭϲϰ͛ϰ͕ϯϵϳ͛ϯ͘ϴϭϯϱ͘ϱϲϬ,ĂůůŝďƵƌƚŽŶy^ůŝĚŝŶŐ^ůĞĞǀĞͲKƉĞŶ ϭϳϱ͕Ϭϵϵ͛ϰ͕ϰϮϱ͛ϯ͘ϵϵϬϱ͘ϱϲϬEŽ'Ž^ĞĂůhŶŝƚ ϭϴϱ͕ϭϬϭ͛ϰ͕ϰϮϲ͛ϰ͘ϬϬϬϱ͘ϴϯϬ,ĂůůŝďƵƌƚŽŶ͞tZ͟WĂĐŬĞƌΘDŝůůŽƵƚǆƚĞŶƐŝŽŶ ϭϵϱ͕ϯϴϯ͛ϰ͕ϲϱϰ͛ϯ͘ϵϵϬϱ͘ϱϲϬEŽ'Ž^ĞĂůhŶŝƚ ϮϬϱ͕ϯϴϰ͛ϰ͕ϲϱϱ͛ϰ͘ϬϬϬϱ͘ϴϯϬ,ĂůůŝďƵƌƚŽŶ͞tZ͟WĂĐŬĞƌΘDŝůůŽƵƚǆƚĞŶƐŝŽŶ Ϯϭϱ͕ϱϱϬ͛ϰ͕ϳϵϭ͛ϯ͘ϴϭϯϱ͘ϱϲϬ,ĂůůŝďƵƌƚŽŶy^ůŝĚŝŶŐ^ůĞĞǀĞͲKƉĞŶ ϮϮϲ͕ϲϮϰ͛ϱ͕ϲϴϰ͛ϯ͘ϳϮϱϰ͘ϵϳϬ,ĂůůŝďƵƌƚŽŶyEEŝƉƉůĞ 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Sundry Procedure6XEMHFW &KDQJHVWR$SSURYHG6XQGU\3URFHGXUHIRU:HOO1&,8$37'6XQGU\;;;;;;$Q\PRGLILFDWLRQVWRDQDSSURYHGVXQGU\ZLOOEHGRFXPHQWHGDQGDSSURYHGEHORZ&KDQJHVWRDQDSSURYHGVXQGU\ZLOOEHFRPPXQLFDWHGWRWKH$2*&&E\WKHULJZRUNRYHU5:2³ILUVWFDOO´HQJLQHHU$2*&&ZULWWHQDSSURYDORIWKHFKDQJHLVUHTXLUHGEHIRUHLPSOHPHQWLQJWKHFKDQJH6HF3DJH'DWH3URFHGXUH&KDQJH1HZ5HTXLUHG"<1+$.3UHSDUHG%\,QLWLDOV+$.$SSURYHG%\,QLWLDOV$2*&&:ULWWHQ$SSURYDO5HFHLYHG3HUVRQDQG'DWH$SSURYDO $VVHW7HDP2SHUDWLRQV0DQDJHU 'DWH 3UHSDUHG )LUVW&DOO2SHUDWLRQV(QJLQHHU 'DWH From:Regg, James B (CED) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] RE: Tyonek A-2 (PTD# 168-091) K-Valve testing Date:Monday, November 22, 2021 4:40:52 PM Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Regg, James B (CED) Sent: Monday, November 22, 2021 4:40 PM To: Chad Helgeson <chelgeson@hilcorp.com> Subject: RE: [EXTERNAL] RE: Tyonek A-2 (PTD# 168-091) K-Valve testing A successful witnessed performance test (11/29?) coupled with the passing tests 11/18 through 11/21 is sufficient for continued operating A-02. Subsequent testing prior to the regulatory required testing in April 2022 is Hilcorp’s decision; any failures of those tests must be reported. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Monday, November 22, 2021 2:33 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; Sandy Reynolds <sreynolds@hilcorp.com>; Brad Blossom <bblossom@hilcorp.com>; Scott Bumbaugh <sbumbaugh@hilcorp.com>; Ben Quesnel <bquesnel@hilcorp.com> Subject: RE: [EXTERNAL] RE: Tyonek A-2 (PTD# 168-091) K-Valve testing Jim Thanks for sending this history along to me. I will give you a call this afternoon to discuss the testing we did over the weekend, but it was all good with the valve. Summary of testing this week with A-2 K-Valve 11/18 - failed to close 2 times when inspector onsite 11/18 – failed to close when troubleshooting (higher bleed off rate) 11/18 – Closed 2 times (85-90 psi) after increasing the flowing pressure on well to 110 psi. 11/18 – Closed Middle of the night, tubing pressure was dropping at valve closed at 96 psi, during normal operations 11/19 – Closed at 85 psi 11/20 – Closed at 88 psi 11/21 – Closed at 91 psi 11/21 – Closed ~ 100 psi (after testing valve, closed on its own) We do not fully understand why the valve did not close on Thursday. In our troubleshooting we did not pumped any liquids down the well, only flowed the well at different rates and pressures, which must have freed it up with some excess gas rate by it. The valve has closed 7 times in the last 4 days of testing. We did not have any situations where the valve failed to close after Thursday, they were 100% closures. To ensure this valve is functioning anytime it could be needed, I would like to propose the following function test schedule for the valve in addition to the required performance test (11/29) to be witness with meter calibrations and any other wells we have worked on that need to be tested, (A- 16, A-10A, & B-3) Date: 11/28 Weekly 12/5 Weekly 12/19 Biweekly 1/2 Biweekly 1/30 Monthly 2/27 Monthly April – Test with the rest of the platform for the 6 month testing cycle If the valve fails to close on any of the these function tests, we will test again, and if it fails 2 function tests, the valve will be pulled with slickline and replaced and retested with the same test frequency. Let me know if this works for the State. Chad From: Regg, James B (CED) <jim.regg@alaska.gov> Sent: Monday, November 22, 2021 10:58 AM To: Chad Helgeson <chelgeson@hilcorp.com> Subject: [EXTERNAL] RE: Tyonek A-2 (PTD# 168-091) K-Valve testing A-2 SVS test results from our records. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Friday, November 19, 2021 3:32 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: Brad Blossom <bblossom@hilcorp.com>; Sandy Reynolds <sreynolds@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com> Subject: Tyonek A-2 (PTD# 168-091) K-Valve testing Jim, I wanted to give you an update of where we are at right now with the K-Valve we discussed yesterday. After our conversation and starting our troubleshooting we were able to get the valve to close 3 times. We increased the flowing pressure to 110 psi by pinching back on the choke, routed it through our test separator, and the valve closed at 85-90 psi with a pretty quick drawdown on the valve. We open the K-Valve and got the rate steady holding a tubing pressure at 110 psi again and drew the well down a little slower, but still pretty quick and it tripped at 73 psi. We opened the K-Valve again and figured we would let it flow normal through the night. During normal operations the K-Valve closed again without any provocation from us at surface during the night. We are currently flowing the well at 103 psi and plan to test it again tonight (when we finish with a production log on another well we can use the test separator). If we can get a 4th trip within approved time and pressure, we won’t plan to make a special slickline run this weekend, to change this valve. I am asking our operators to test the valve 1 time per day through this weekend and I will report back to you on Monday how they did and we can come up with plan for more frequent testing until we have confidence in the valve to trip and work as needed under normal operating conditions. Let me know if you want us to do something different with this well or testing the valve over the weekend. Regards Chad Helgeson ASC Operations Engineer From:Regg, James B (CED) To:AOGCC Records (CED sponsored) Subject:FW: Tyonek A-2 (PTD# 168-091) K-Valve testing Date:Monday, November 22, 2021 3:46:03 PM Attachments:SVS NCIU A-02 History 11-19-21.pdf Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Regg, James B (CED) Sent: Monday, November 22, 2021 10:58 AM To: Chad Helgeson <chelgeson@hilcorp.com> Subject: RE: Tyonek A-2 (PTD# 168-091) K-Valve testing A-2 SVS test results from our records. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Friday, November 19, 2021 3:32 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: Brad Blossom <bblossom@hilcorp.com>; Sandy Reynolds <sreynolds@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com> Subject: Tyonek A-2 (PTD# 168-091) K-Valve testing Jim, I wanted to give you an update of where we are at right now with the K-Valve we discussed yesterday. After our conversation and starting our troubleshooting we were able to get the valve to close 3 times. We increased the flowing pressure to 110 psi by pinching back on the choke, routed it through our test separator, and the valve closed at 85-90 psi with a pretty quick drawdown on the valve. We open the K-Valve and got the rate steady holding a tubing pressure at 110 psi again and drew the well down a little slower, but still pretty quick and it tripped at 73 psi. We opened the K-Valve again and figured we would let it flow normal through the night. During normal operations the K-Valve closed again without any provocation from us at surface during the night. We are currently flowing the well at 103 psi and plan to test it again tonight (when we finish with a production log on another well we can use the test separator). If we can get a 4th trip within approved time and pressure, we won’t plan to make a special slickline run this weekend, to change this valve. I am asking our operators to test the valve 1 time per day through this weekend and I will report back to you on Monday how they did and we can come up with plan for more frequent testing until we have confidence in the valve to trip and work as needed under normal operating conditions. Let me know if you want us to do something different with this well or testing the valve over the weekend. Regards Chad Helgeson ASC Operations Engineer Hilcorp Alaska LLC chelgeson@hilcorp.com 907-777-8405 (O) 907-229-4824 (C) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1680910 N COOK INLET UNIT A-02 Date Insp/Oper Test Reason Comments 01/30/97 IN 180 P Passed test P Passed test 07/17/97 IN 180 P Passed test P Passed test 05/21/98 OP Misc P Passed test P Passed test 04/12/99 IN 180 P Passed test P Passed test 10/21/99 IN 180 P Passed test P Passed test 10/20/00 IN 180 P Passed test P Passed test 06/19/01 IN 180 P Passed test 43 See Comments 43 See Comments Both SSV and SSSV failed. All valve failures cycled and retested "OK". 08/28/01 IN 90 P Passed test P Passed test P Passed test 09/18/02 IN 180 P Passed test P Passed test 02/20/03 IN 180 P Passed test P Passed test P Passed test No Gauges on OA 08/21/03 IN 180 P Passed test P Passed test P Passed test 04/29/04 IN 180 P Passed test P Passed test P Passed test 11/20/04 IN 180 P Passed test P Passed test P Passed test 05/27/05 OP 180 P Passed test P Passed test 11/22/05 OP 180 P Passed test 8 Failed to close A-2 SSSV Cycled valve. Passed on Retest. A-5 SSSV Cycled valve. Passed on Retest. 05/24/06 IN 180 P Passed test P Passed test P Passed test Shut in PSI- A1/280, A2/460, A3/280, A4/300, A5/460, A6/290, A7/280, A8/380, A9/420 A10/360, A12/290, B1/375, B3/440. note: 5/26/2006 put new SSSV in A4 and tested sat. note: 6/7/2006 put new SSSV in A6 and tested sat. 11/20/06 OP Retest P Passed test P Passed test P Passed test 11/20/06 IN 180 P Passed test P Passed test 9 Failed to hold DP Tyonek Platform SVS tests. Operator was made aware repair retest of failures are reqired within 2 weeks. AOGCC needs to be notified to have the opportunity to witness retests. 05/29/07 IN 180 P Passed test P Passed test P Passed test 11/08/07 IN 180 P Passed test P Passed test P Passed test 06/03/08 IN 180 P Passed test P Passed test P Passed test 11/13/08 IN 180 30 Initially Tripped Below Required Trip PSI - Passed Retest P Passed test P Passed test 02/13/09 IN 180 P Passed test P Passed test 90 Initially Failed to hold DP - Passed Retest All three failures (A-2 SSSV, A-6 SSSV, and A-9 SSV) held on re-test. All re-tests witnessed by Lou Grimaldi. Testing was done on two dates (2-10 and 2-12) per Inspector's convenience. 05/05/09 OP 180 P Passed test P Passed test P Passed test Pilot Test Result SSV Test Result SSSV Test Result Page 1 of 3 Date Insp/Oper Test Reason CommentsPilot Test Result SSV Test Result SSSV Test Result 04/25/18 IN 180 P Passed test P Passed test 9 Failed to hold DP A3 sssv failed to hold D.P., re tested and passed A15 failed to close A2 and A5 failed to hold D.P. 04/30/18 IN Retest P Passed test P Passed test P Passed test 07/25/18 IN 90 P Passed test P Passed test 9 Failed to hold DP A-2 SSSV FAILED TO HOLD DP 07/27/18 OP Retest P Passed test P Passed test P Passed test 10/12/18 IN 180 P Passed test P Passed test P Passed test 04/09/19 OP 180 P Passed test P Passed test P Passed test 08/09/19 OP Misc P Passed test P Passed test P Passed test 10/11/19 IN 180 P Passed test P Passed test P Passed test 04/18/20 OP 180 P Passed test P Passed test 9 Failed to hold DP Pollard wireline on A2 to pull K valve and repair. Today 4/18/20 04/21/20 OP Retest P Passed test P Passed test P Passed test 10/08/20 OP 180 P Passed test P Passed test P Passed test 04/01/21 IN 180 P Passed test P Passed test NT Not tested Unable to test A-02 SSSV/K-valve due to facility shutting down multiple times. A5 sssv failed to hold DP, stroking valve and getting wire line out A2 sssv was a "NT" - unable to test A-02 SSSV/K-valve. Inspector did not witness subsequent test. A2 K valve failed to close, currently working to get valve to close (on a separate report 04/01/21 OP Misc P Passed test P Passed test 8 Failed to close Test sssv/K valve after state guy left. Failed to close 04/08/21 OP Retest P Passed test P Passed test P Passed test 07/03/21 IN 90 P Passed test P Passed test 8 Failed to close A2 K valve failed to close 07/08/21 OP Retest P Passed test 10/31/21 OP 180 P Passed test P Passed test 8 Failed to close A2 K valve failed to close, within 48 hrs we will get line to replace or shut well in 11/18/21 IN Retest P Passed test P Passed test 8 Failed to close A2 K valve failed to close, 48 hrs to fix. Page 3 of 3 Date Insp/Oper Test Reason CommentsPilot Test Result SSV Test Result SSSV Test Result 06/15/09 OP 90 P Passed test P Passed test P Passed test 11/23/09 IN 180 P Passed test P Passed test P Passed test 05/21/10 IN 180 P Passed test P Passed test 9 Failed to hold DP 05/28/10 OP Retest NT Not tested NT Not tested P Passed test 11/14/10 IN 180 P Passed test P Passed test P Passed test 05/24/11 IN 180 P Passed test P Passed test 9 Failed to hold DP Retest A-12 SSSV on 5/25/2011 still failed to hold D/P A-2 SSSV failed to hold D/P. Maximum shut in pressure attained during SVS test was 295 psi.125 psi D/P etst performed. FTP taken from LPP sensing point between the choke & the tree. Two downhole failures witnessed. Requested the Operator give AOGCC opportunity to witness retests of these downhole valves after they had been on production 24 to 48 hours after repair or wate 05/27/11 OP Retest P Passed test P Passed test P Passed test 11/15/11 IN 180 P Passed test P Passed test P Passed test 04/14/12 IN 180 P Passed test P Passed test P Passed test 10/25/12 OP 180 P Passed test P Passed test P Passed test 04/30/13 IN 180 P Passed test P Passed test P Passed test 11/12/13 IN 180 P Passed test P Passed test 90 Initially Failed to hold DP - Passed Retest A-02 retested, passed 11/12/13 A-04 retested, passed 11/12/13 AOGCC onsite during retests 04/12/14 OP 180 P Passed test P Passed test P Passed test 10/09/14 IN 180 P Passed test P Passed test P Passed test 04/09/15 IN 180 P Passed test P Passed test P Passed test 10/24/15 IN 180 P Passed test P Passed test P Passed test 04/22/16 OP 180 P Passed test P Passed test P Passed test 10/21/16 IN 180 P Passed test P Passed test P Passed test 01/14/17 IN 90 P Passed test P Passed test P Passed test A-5 SSSV INITIALLY FAILED D.P; FUNCTIONED AND PASSED RETEST A-2 SENSING LINE FULL OF WATER. 8 wells inspected, no exceptions noted. A-05 SSSV initially failed the pressure test and was cycled and passed a retest. The A-02 pilot tripped properly but the pilot pressure sensing was was full of water. I asked Mr. Alvord to establish a water blowdown 04/16/17 IN 180 P Passed test P Passed test P Passed test 10/16/17 IN 180 P Passed test P Passed test 9 Failed to hold DP Valve functioned and did not pass retest. 01/24/18 OP Misc P Passed test P Passed test P Passed test Page 2 of 3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon LJ Plug Perforations Ll Fracture Stimulate Ll Pull Tubing Ll Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Installed SSC-SSSV ❑� 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Y ll r— vei'l"� Name: Hilcorp Alaska, LLC Development ❑� Exploratory ❑ Stratigraphic ❑ Service ❑ 168-091 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: 1 ns Anchorage, AK 99503 50-883-20018-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0017589 N Cook Inlet Unit A-02 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A North Cook Inlet / Tertiary Gas Pool 11. Present Well Condition Summary: Total Depth measured 8,429 feet Plugs measured 6,790 feet true vertical 7,227 feet Junk measured 6,790 feet Effective Depth measured 6,000 feet Packer measured See schematic feet true vertical 5,158 feet true vertical See schematic feel Casing Length Size MD TVD Burst Collapse Structural 385' 30" 385' 385' Conductor 621' 16" 621' 621' 1,640 psi 630 psi Surface 2,637' 10-3/4" 2,637' 2,432' 3,580 psi 2,090 psi Intermediate Production 7,189' 7" 7,189' 6,167' 4,360 psi 3,270 psi Liner Perforation depth Measured depth 4,445 - 6,612 feet True Vertical depth 3,916 - 5,674 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6 / J-55 & 12.75 / J-55 6,626' (MD) 5,686' (TVD) Packers and SSSV (type, measured and true vertical depth) See schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 4226 1 0 54 Subsequent to operation: 0 4180 3 27 110 14. Attachments (requimd per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations Exploratory ❑ Development ❑✓ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas 2 WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-358 Authorized Name: Stan W. Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlowe@hilcorp.com Authorized Signature: Date: a 3 Contact Phone: (907) 283-1329 Form 10-404 Revised 412017 RBDMSttA4SEP 0 3 2019 Submit original only North Cook Inlet Well: NO A-02 Last SCHEMATIC PTD: 68 09t1ed: 07/01/1994 API: 50-883-20018-00 HHmen Al.ke. LLC RKB: MLLW =116' PBTD: 6,790' TD: 8,429' CASING DETAIL Size Wt Grade Conn ID Top Bim 30" 40.2' Conductor BT&C 29.00 Surf 385' 16" 65 H-40 Mad EUEBIRD3.958 15.250 Surf 621' 10-3/4" 45.5 J-55 BT&C 9.950 Surf XXX 51 J-55 BT&C 9.850 XXX 2,637' 7" 26 J-55 BT&C 6.276 Surf 80' 23 J-55 BT&C 6.366 80' 6,659' 26 1-55 BT&C 6.276 6,659' 7,189' TUBING DETAIL 4-1/2" 12.60 1-55 Mod 3.958 Surf 348' 40.2' 40.2' BT&C FMC/OCT 6" 3M Tubing Hanger 1 -344' 4-1/2" 12.75 J-55 Mad EUEBIRD3.958 2 348' 6,626' 3.813 4.860 Halliburton "XXO" SCSSV Nipple 4,371' 3,858' 3.813 IEWELRY DETAII No Depth (MD) Depth (TVD) ID OD Item 40.2' 40.2' FMC/OCT 6" 3M Tubing Hanger 1 -344' '"344' 2.813" SSC-SSSV-Weatherford PB (K -Valve) 2 349' 349' 3.813 4.860 Halliburton "XXO" SCSSV Nipple 4,371' 3,858' 3.813 5.750 Halliburton Upper "PBR" Assembly 3 4,380' 3,865' 3.990 5.560 Ratch Latch Seal Unit 4,381' 3,866' 3.880 5.830 Halliburton "VSR" Packer 4 4,419' 3,896' 3.813 5.560 Halliburton X Landing Nipple 5 4,539' 3,989' 3.813 5.560 Halliburton XD Sliding Sleeve - Closed 6 4,548' 3,996' 3.990 5.560 No Go Seal Unit 7-j-_ ,549' 3,997' 4.000 5.830 Halliburton "AWR" Packer & Millout Extension 8 4,637' 4,066' 3.813 5.560 Halliburton XD Sliding Sleeve - Closed 9 4;645' 4,072' 3.990 5.560 No Go Seal Unit 10 4,647' 4,074' 4.000 5.830 Halliburton "AWR" Packer & Millout Extension it 4,704' 4,118' 3.813 5.560 Halliburton XD Sliding Sleeve -Closed 12 4,738' 4,144' 3.990 5.560 No Go Seal Unit 13 4,740' 4,146' 4.000 5.830 Halliburton "AWR" Packer & Millout Extension 14 4,992' 4,341' 3.990 5.560 No Go Seal Unit 15 4,993' 4,342' 4.000 5.830 Halliburton "AWR" Packer & Millout Extension 16 5,064' 4,397' 3.813 5.560 Halliburton XD Sliding Sleeve - Open 17 5,099' 4,425' 3.990 5.560 No Go Seal Unit 18 5,101' 4,426' 4.000 5.830 Halliburton "AWR" Packer & Millout Extension 19 5,383' 4,654' 3.990 5.560 No Go Seal Unit 20 1 5,384' 1 4,655' 1 4.000 5.830 Halliburton "AWR" Packer & Millout Extension 21 5,550' 14,791' 3.813 5.560 Halliburton XA Sliding Sleeve -Open 22 6,624' 5,684' 3.725 4.970 Halliburton XN Nip le 23 6,625' 5,685' 4.000 5.561 1 Wireline Re -Entry Guide Notes: 1/11/69 - Isolation Sleeve Patch -4,539' 1/11/69 - Isolation Sleeve Patch - 5,063' 1/21/15 - Sand in tubing at 6,000' 7/17/11- Fill covering Perfs below 6,029' Updated By: JUL 08/26/2019 B .R1-_-- elae4o I i f SCHEMATIC North Cook Inlet Well: NCI A-02 Last Completed: 07/01/1994 PTD: 168-091 API: 50-883-20018-00 Updated By: JU 06/21/2019 PERFORATION DETAIL Zone Top (NID) Btm (MD) Top (TVD) Btm (TVD) FT SPF Date Status CI -1.0 4,445' 4,535' 3,916' 3,986' 90' CI -2.0 4,554' 4,630' 4,001' 4,060' 76' CI -3.0 4,658 4,670' 4,081' 4,091' 14' CI -5.0 4,800' 4,821' 4,192' 4,208' 21' CI -6.0 4,886' 4,904' 4,259' 4,273' 18' CI -8.0 5,047' 5,059' 4,384' 4,393' 12' 0-9.0 5,120' 5,142' 4,441' 4,459' 22' CI -11.0 5,238' 5,252' 4,536' 4,547' 14' B-6 5,504' 5,510' 4,753' 4,758' 6' B-7 5,522' 5,527' 4,768' 4,772' 5- C-2 5,628' 5,632' 4,854' 4,858' 4- C-3 5,676' 5,680' 4,894' 4,897' 4' C-4 5,702' 5,708' 4,915' 4,920' 6' C-5 5,715' 5,730' 4,925' 4,938' 15' D-3 5,798' 5,808' 4,993' 5,001' 30' D-4 5,855' 5,862' 5,039' 5,045' 7- D-5 5,879' 5,888' 5,059' 5,066' 9' E-4 5,940' 5,945' 5,109' 5,113' 5' E-8 6,002' 6,011' 5,159' .5,166' 9' F-3 6,082' 6,090' 5,225' 5,232' 8' F-6 6,140' 6,148' 5,273' 5,280' 8' G-1 6,176' 6,203' 5,303' 5,326' 27' G-5 6,260' 6,286' 5,373' 5,395' 26' H-8 1 61412' 6,430' 5,502' 5,517' 18' J-2 6,602' 6,612' 5,665' 5,674' 10' Updated By: JU 06/21/2019 Hilcorp Alaska, LLC Hikorp A"LLCWell Operations Summary Rig API Number Well Permit NumbeStart Date End Date Slickline 50-833-20018-00-00 168-091. 1 8/2/2019 8/6/2019 Daily Operations: 08/02/2019 - Friday M/U K-VALVE TO X-LOCK W/ 3.82" PACKING - 3.84"O-RING. P/T LUB. & WLV'S TO 250PSI LOW 150OPSI HIGH - GOOD TEST. RIH W/ CHECK SET TOOL TO 351'KB W/ TOOL POOH. PIN SHEARED VALVE SET. LAY DOWN LUB. SECURE WELL FOR PRODUCTION TO FLOW WELL. 08/03/2019 —Saturday MORNING MEETING, ISA, PERMIT. STAND BY FOR CLOSURE TEST ON K- VALVE. TUBING PRESSURE DOWN TO 53 PSI VALVE WONT SHUT. CALL TOWN. P/U LUB. STAB ON RISER SHUT IN WELL. RIH W/ 4 1/2" GS TO 351'KB W/ TOOL POOH W/ K-VALVE - VALVE STUCK OPEN FULL OF MUD. RIH W/ 3.25" BLIND BOX TO 5230'KB, NO OBSTRUCTION, DID NOT SEE FLUID LEVEL, DID NOT TAG, POOH. LAY DOWN LUB. SECURE WELL FOR PRODUCTION TO FLOW. CLEAN AREA STAND BY FOR CHOPPER. 08/04/2019-Sunday NO OPERATIONS TO REPORT 08/05/2019 - Monday ARRIVE TYONEK PLATFORM. TGSM, JSA, PERMIT. TIE ROPE SOCKET P/U LUB. STAB ON RISER P/T LUB. & WLV'S TO 250 LOW 1500PSI HIGH- PASS. RIH W/41/2" BRAIDED LINE BRUSH. CLEAN SSSV NIPPLE & TUBING POOH. PRESSURE UP LUB. T0450PSI TO OPEN K-VALVE. RIH W/ 4 1/2" X-LINE W/ K-VALVE TO 351'KB W/ TOOL SET. POOH. RIH W/ CHECK SET TOOL TO 351'KB W/ TOOL POOH. PIN SHEARED K-VALVE SET. OOH STANDBY FOR FUNCTION TEST. VALVE STUCK OPEN TUBING PRESSURE DOWN TO 54#. RIH W/ 41/2" GS TO 351'KB W/ TOOL. POOH W/ VALVE. LAY DOWN LUB. SECURE WELL FOR NIGHT. 08/06/2019-Tuesday MORNING MEETING, ISA, PERMIT. STAND BY FOR CHOPPER TO P/U K-VALVE SEND TO TOWN FOR REDRESS. P/U LUB. STAB ON RISER P/T TO 250 LOW 150OPSI HIGH - GOOD TEST. RIH W/ BRAIDED LINE BRUSH TO SSSV NIPPLE 351'KB MAKE SEVERAL PASSES WHILE PUMPING DIESEL POOH. PRESSURE UP LUB. TO 450PSI W/ GAS TO OPEN K-VALVE. RIH TO 351'KB W/ TOOL SET, POOH. RIH W/ CHECK SET TOOL TO 351'KB W/ TOOL, POOH. PIN SHEARED - VALVE SET. STAND BY FOR CLOSURE TEST. CLOSURE TEST GOOD. RIG DOWN SLICKLINE SECURE WELL FOR PRODUCTION. STAND BY FOR CHOPPER. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Stan W. Golis Operations Manager Hilcorp Alaska, LLC. 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99519-6612 Alaska Oil and Gas Conservation Commission Re: North Cook Inlet Field, Tertiary Gas Pool, N. Cook Inlet Unit A-02 Permit to Drill Number: 168-091 Sundry Number: 319-358 Dear Mr. Golis: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .00gcc.alasko.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this day of August, 2019. 8BDMS rte' AUG 1 31019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 "E- CVD AUG 0 2 20119 A r% r� r' r% 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ b' tbown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Install SSC-SSSV ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q Stratigraphic ❑ Service ❑ 168-091 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-883-20018-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑Q N Cook Inlet Unit A-02 9. Property Designation (Lease Number): • 10. Field/Pool(s): ADL0017589 North Cook Inlet/ Tertiary Gas Pool If. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8,429 7,227 6,000 5,158 -200 psi 6,790 6,790 Casing Length Size MD TVD Burst Collapse Structural 385' 30" 385' 385' Conductor 621' 16" 621' 621' 1,640 psi 630 psi Surface 2,637' 10-3/4" 2,637' 2,432' 3,580 psi 2,090 psi Intermediate Production 7,189' 7" 7,189' 16,167' 4,360 psi 3,270 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4,445 - 6,612 3,916 - 5,674 4-1/2" 12.6 / J-55 & 12.75 / J-55 6,626 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Packers (x7) See Schematic / Hallibunon XXO SCSSV See Schematic / 349 (MD) / 349 (TVD) 12. Attachments: Proposal Summary D Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 8/19/2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑v ' WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: ,l k+ z�,..t-L GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan W. Golfs Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlowe f hilcor .Com �1 p Contact Phone: (907) 283-1329 �� I I Authorized Signature: Date: b 3 t 1 COMMISSION USE ONLY Conditions of approval: Notify Commission so at a representative may witness Sundry Number: 31q-35� Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: I pp r /�� %F �tJ� #Le_sS KewriLvt P2r�irmu_,. Te RBDMS� AUG 13 2019 Post Initial Injection MIT Req'd? Yes ❑ No ❑ �/ (.� Spacing Exception Required? Yes ❑ No Subsequent Form Required: 1 a -[ b t APPROVED BY �y Approved by: COMMISSIONER THE COMMISSION O J Date: it Ul��a rm 10-4 3 Re d 12017 Approved application i �T�/y�� tRr1rr 14t�rLdate of approval. Submit Form and Aftac me is in Duplicate � lq 'PLA$/6l?l n Hil.,rp Alk, LLC Well Work Prognosis Well Name: NCIU A-02 API Number: 50 -883 -20018 -00 -00 - Current Status: Gas Well Leg: Leg 3 Estimated Start Date: August 19, 2019 Rig: N/A Reg. Approval Required? 403 Date Reg. Approval Received: Regulatory Contact: Juanita Lovett Permit to Drill Number: 168-091 First Call Engineer: Dan Marlowe Office: 907-283-1329 Cell: 907-398-9904 Second Call Engineer: Stan Golis Office: 907-777-8356 71 Current Bottom Hole Pressure: 345 psi @ 5,140' TVD 0.067 psi/ft based on SIBHP Maximum Expected BHP: 345 psi @ 5,140' TVD 0.067 psi/ft based on SIBHP Maximum Potential Surface Pressure: -200 psi Using 0.1 psi/ft gradient per 20 AAC 25.280(b)(4) Brief Well Summary After Slickline bailing in July, the retrievable SSSV has been difficult to set and test. If we are not successful reinstalling the retrievable, this project will install a subsurface controlled subsurface safety valve (SSC-SSSV) in accordance with Guidance Bulletin 10-004. SSC-SSSV Suitability Evaluation: Well historic parameters Gross GasT 4.5 mmcfd FTP 60 psig Temp 53F This safety valve will be setup with a trip pressure of -80 psig. We will hold backpressure on the well with the production choke to maintain a normal FTP of -100 psig. To test the valve we will open the production choke, lowering the FTP and trip the SC-SSSV. To reset the valve the well pressured up to above the trip pressure then gradually reopened to the normal operating range. Procedure: 1. MIRU Slick -line, PT lubricator to 1,500 psi Hi 250 Low. 2. RIH and set the subsurface controlled subsurface safety valve. 3. Turn well over to production. 4. Conduct a SVS test within 5 days after stabilized flow. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. McMurry-Macco PB Subsurface Safety valve cut sheet. (Alternate Halliburton K -valve may also be used depending on availability) R corp Alaska, LLC RKB: MLLW - 116' PBTD: 6,790' TD: 8,429' SCHEMATIC CASING DETAII North Cook Inlet Well: NO A-02 Last Completed: 07/01/1994 PTD: 168-091 API: 50-883-20018-00 Size Wt Grade Conn ID Top I 30" 40.2' Conductor 29.00 Surf 16" 65 H-40 MBRDDE 15.250 Surf 10-3/4" 45.5 J-55 BT&C 9.950 Surf 51 J-55 BT&C 9.850 XXX d6,659' 7" 26 1-55 BT&C 6.276 Surf 23 J-55 BT&C 6.366 80' 1,896' 3.813 TUBING DETAII 4-1/2" 12.60 J-55 Mod 3.958 Surf 348' 40.2' 40.2' 1 FMC/OCT 6" 3M Tubing Hanger 1 349' 4-1/2" 12.75 J-55 MBRDDE 3.958 348' 6,626' 3.813 5.750 Halliburton Upper "PBR" Assembly 4,380' 3,865' 3.990 IEWELRY DETAII No Depth (MD) Depth (TVD) ID OD Item 40.2' 40.2' 1 FMC/OCT 6" 3M Tubing Hanger 1 349' 349' 3.813 4.860 Halliburton "XXO" SCSSV Nipple 2 4,371' 3,858' 3.813 5.750 Halliburton Upper "PBR" Assembly 4,380' 3,865' 3.990 5.560 Ratch Latch Seal Unit 4,381' 3,866' 3.880 5.830 Halliburton "VSR" Packer 3 4,419' 1,896' 3.813 !.560 Halliburton X Landing Nipple 4 4,539' 3,989' 3.813 5.560 Halliburton XD Sliding Sleeve - Closed 5 4,548' 3,996' 3.990 5.560 No Go Seal Unit 6 4,549' 3,997' 1 4.000 5.830 Halliburton "AWR" Packer & Millout Extension 7 4,637' 4,066' 3.813 5.560 Halliburton XD Sliding Sleeve - Closed 4,645' 4,072' 3.990 5.560 No Go Seal Unit 11901 4,647' 4,074' 4.000 5.830 Halliburton "AWR" Packer & Millout Extension 4,704' 4,118' 3.813 5.560 Halliburton XD Sliding Sleeve - Closed 11 4,738' 4,144' 3.990 5.560 No Go Seal Unit 12 4,740' 4,146' 4.000 5.830 Halliburton "AWR" Packer &Millout Extension 13 4,992' 4,341' 3.990 5.560 No Go Seal Unit 14 4,993' 4,342' 4.000 5.830 Halliburton "AWR" Packer & Millout Extension 15 5,064' 4,397' 3.813 5.560 Halliburton XD Sliding Sleeve - Open 16 5,099' 4,425' 3.990 5.560 No Go Seal Unit 17 5,101' 1,426' 4.000 5.830 Halliburton "AWR" Packer & Millout Extension 18 5,383' 4,654' 3.990 5.560 No Go Seal Unit 19 5,384' 4,655 4.000 5.830 Halliburton "AWR" Packer & Millout Extension 20 5,550' 4,791' 3.813 5.560 Halliburton XA Sliding Sleeve -Open 21 6,624' 5,684' 3.725 4.970 Halliburton XN Nipple 22 6,625' 5,685' 4.000 5.561 Wireline Re -Entry Guide Notes: 1/11/69- Isolation Sleeve Patch -4,539' 1/11/69- Isolation Sleeve Patch -5,063' 1/21/15 -Sand in tubing at 6,000' 7/17/11 -Fill covering Pers below 6,029' Updated By: JUL 06/21/2019 u caro Alaska, LLC SCHEMATIC North Cook Inlet Well: NCI A-02 Last Completed: 07/01/1994 PTD: 168-091 API: 50-883-20018-00 Updated By: JLL 06/21/2019 PERFORATION DETAIL Zone Top(MD) Btm (MD) Top (TVD) Btm (TVD) FT SPF Date Status CI -1.0 4,445' 4,535' 3,916' 3,986' 90' C1-2.0 4,554' 4,630' 4,001' 4,060' 76' CI -3.0 4,656' 4,670' 4,081' 4,091' 14' CI -5.0 4,800' 4,821' 4,192' 4,208' 21' CI -6.0 4,886' 4,904' 4,259' 4,273' 18' C1-8.0 5,047' 5,059' 4,384' 4,393' 12' 0-9.0 5,120' 5,142' 4,441' 4,459' 22' CI -11.0 5,238' 5,252' 4,536' 4,547' 14' B-6 5,504' 5,510' 4,753' 4,758' 6- B-7 5,522' 5,527' 4,768' 4,772' 5- C-2 5,628' 5,632' 4,854' 4,858' 4- C-3 5,676' 5,680' 4,894' 4,897' 4' C-4 5,702' 5,708' 4,915' 4,920' 6- C-5 5,715' 5,730' 4,925' 4,938' 15' D-3 5,798' 5,808' 4,993' 5,001' 10' D-4 5,855' 5,862' 5,039' 5,045' 7' D-5 5,879' 5,888' 5,059' 5,066' 9' E-4 5,940' 5,945' 5,109' 5,113' 5' E-8 6,002' 6,011' 5,159' 5,166' 9' F-3 6,082' 6,090' 5,225' 5,232' 8- F-6 6,140' 6,148' 5,273' 5,280' 8' G-1 6,176' 6,203' 5,303' 5,326' 27' G-5 6,260' 6,286' 5,373' 5,395' 26' H-8 6,412' 6,430' 5,502' 51517' 18' J-2 6,602' 6,612' 5,665' 5,674' 10' Updated By: JLL 06/21/2019 H Hilcoro Alaska, LLC RKB: MLLW = 116' PBTD6,790' TD: 8,429' PROPOSED CASING DETAIL North Cook Inlet Well: NCI A-02 Last Completed: 07/01/1994 PTD: 168-091 API: 50-883-20018-00 Size Wt Grade Conn ID Top 348' 30" 1 40.2' Conductor 29.00 Surf 16" 65 H-40 MBRDUE 15.250 Surf 10.3/4" 45.5 J-55 BT&C 9.950 Surf M6,659' 5.750 51 J-55 BT&C 9.850 XXX Ratch Latch Seal Unit 26 J-55 BT&C 6.276 Surf 7" 23 J-55 BT&C 6.366 80' 4 4,539' 26 J-55 BT&C 6.276 6,659' TUBING DETAIL 4-1/2" 12.60 J-55 Mod 3.958 Surf 348' 40.2' 1 40.2' FMC/OCT 6" 3M Tubing Hanger ±344' 4-1/2" 12.75 J-55 MBRDUE 3.958 348' 6,626' 3.813 4.860 Halliburton "XXO" SCSSV Nipple 2 4,371' 3,858' 3.813 JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item 40.2' 1 40.2' FMC/OCT 6" 3M Tubing Hanger ±344' ±344' 2.813" SSC-sssv 1 349' 349' 3.813 4.860 Halliburton "XXO" SCSSV Nipple 2 4,371' 3,858' 3.813 5.750 Halliburton Upper "PBR" Assembly 4,380' 3,865' 3.990 5.560 Ratch Latch Seal Unit 4,381' 3,866' 3.880 5.830 Halliburton "VSR" Packer 3 4,419' 3,896' 3.813 5.560 Halliburton X Landing Nipple 4 4,539' 3.813 5.560 Halliburton XD Sliding Sleeve - Closed 5 4,548' 3.990 5.560 No Go Seal Unit 6 4,549' 4.000 5.830 Halliburton "AWR" Packer & Millout Extension 7 4,637' 3.813 5.560 Halliburton XD Sliding Sleeve -Closed 8 4,645' M11 3.990 5.560 No Go Seal Unit 9 4,647' 4.000 5.830 Halliburton "AWR" Packer & Millout Extension 30 4,704' 3.813 5.560 Halliburton XD Sliding Sleeve - Closed 11 4,738' 3.990 5.560 No Go Seal Unit 12 4,740' 4.000 5.830 Halliburton "AWR" Packer & Millout Extension 13 4,992' 4,341' 3.990 5.560 No Go Seal Unit 14 14,993' 4,342' 4.000 5.830 Halliburton "AWR" Packer & Millout Extension 15 5,064' 4,397' 3.813 5.560 Halliburton XD Sliding Sleeve - Open 16 5,099' 4,425' 3.990 5.560 No Go Seal Unit 17 5,101' 4,426' 4.000 5.830 Halliburton "AWR" Packer & Millout Extension 18 5,383' 4,654' 3.990 5.560 No Go Seal Unit 19 5,384' 4,655' 4.000 5.830 Halliburton "AWR" Packer & Millout Extension 20 5,550' 4,791' 3.813 5.560 Halliburton XA Sliding Sleeve - Open 21 6,624' 5,684' 3.725 4.970 Halliburton XN Nipple 22 6,625' 5,685' 4.000 5.561 Wireline Re -Entry Guide Notes: 1/11/69 - Isolation Sleeve Patch - 4,539' 1/11/69 - Isolation Sleeve Patch - 5,063' 1/21/15 - Sand in tubing at 6,000' 7/17/11- Fill covering Perts below 6,029' Updated By: JUL 06/21/2019 H corn Alaska. LLC PROPOSED North Cook Inlet Well: NCI A-02 Last Completed: 07/01/1994 PTD: 168-091 API: 50-883-20018-00 Updated By: JLL 06/21/2019 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT SPF Date Status CI -1.0 4,445' 4,535' 3,916' 3,986' 90' CI -2.0 4,554' 4,630' 4,001' 4,060' 76' CI -3.0 4,656' 4,670' 4,081' 4,091' 14' CI -5.0 4,800' 4,821' 4,192' 4,208' 21' 0-6.0 4,886' 4,904' 4,259' 4,273' 18' CI -8.0 5,047' 5,059' 4,384' 4,393' 12' 0-9.0 5,120' 5,142' 4,441' 4,459' 22' CI -11.0 5,238' 5,252' 4,536' 4,547' 14' B-6 5,504' 5,510' 4,753' 4,758' 6- B-7 5,522' 5,527' 4,768' 4,772' 5- C-2 5,628' 5,632' 4,854' 4,858' 4' C-3 5,676' 5,680' 4,894' 4,897' 4- C-4 5,702' 5,708' 4,915' 4,920' 6- C-5 5,715' 5,730' 4,925' 4,938' 15' D-3 5,798' 5,808' 4,993' 5,001' 10' D-4 5,855' 5,862' 5,039' 5,045' 7- D-5 5,879' 5,888' 5,059' 5,066' 9' E-4 5,940' 5,945' 5,109' 5,113' 5' E-8 6,002' 6,011' 5,159' 5,166' 9' F-3 6,082' 6,090' 5,225' 5,232' 8' F-6 6,140' 6,148' 5,273' 5,280' 8- G-1 6,176' 6,203' 5,303' 5,326' 27' G-5 6,260' 6,286' 5,373' 5,395' 26' H-8 6,412' 6,430' 5,502' 5,517' 18' J-2 6,602' 6,612' 5,665' 5,674' 10' Updated By: JLL 06/21/2019 McMurry-Macco McMurry-Macco PB Subsurface Safety Valve Advantages • Large flow area. • No flow through moving parts of safety valve. • No hydraulic seals. Closing force is transmitted through liquid -filled bellows. • Predictable and repeatable valve performance. • Snap -action closure. Valve disc does not throttle in flow stream. • Suitable for gas lift wells. • Easily field tested. With use of a convenient test stand, the PB safety valve can be tested and reset. • No depth limitation. The PB is suitable for a wide variety of special applications. The PB is wireline retrievable and can be sus- pended and packed off in any standard landing nipple with the appropriate locking device. The PB can also be suspended and packed off in the tubing string with a collar lock mandrel. The PB is available in a 50 to 3,000 psi range (PB) and a 100 to 10,000 psi range (HP -PB). Features • Subsurface control. • Wireline retrievability. • 50 to 10,000 psi operating range. • Bellows protection unit. • Positive closing pressure. • Hard and soft disc -seat closing seal. API 14A, ASME SPPE-1 specifications and are available for class I, or 3S service. 72 Schwartz, Guy L (CED) From: Dan Marlowe <dmarlowe@hilcorp.com> Sent: Friday, August 2, 2019 1:30 PM To: Schwartz, Guy L (CED) Cc: Juanita Lovett Subject: RE: [EXTERNAL] RE: NCIU A-02 PTD 168-091 Attachments: Halliburton K Valve.pdf Guy This one is a 4" Halliburton K -valve hung from a 4-1/2" lock Serial Number K29A Test Rack Opening Pressure —150# Test Rack Closing Pressure — 70 If Halliburton Cut sheet is attached From: Schwartz, Guy L (CED) [mailto:guy.schwartz@alaska.gov] Sent: Friday, August 2, 2019 11:00 AM To: Dan Marlowe <dmarlowe@hilcorp.com> Cc: Juanita Lovett <jlovett@hilcorp.com> Subject: [EXTERNAL) RE: NCIU A-02 PTD 168-091 Dan, You have verbal approval to proceed with the K Valve installation as proposed in you sundry application. As stated below you will need to have a witnessed performance test of the valve within 5 days of installation. Also, could you forward the design set up (ie dome pressure etc that to our records. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office from the vendor once you get them so we can add CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s)- It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226) or (Guv.schwartz@alaska aovl. From: Dan Marlowe <dmarlowe@hilcorp.com> Sent: Friday, August 2, 2019 10:45 AM To: Schwartz, Guy L (CED) <guv.schwartzC@alaska.gov> Cc: Juanita Lovett <ilovett@hilcoro.com> Subject: RE: NCIU A-02 PTD 168-091 Guy As discussed we are facing logistical constraints due to crane overhaul activity and have a limited time constraint to execute this work. Hilcorp therefore requests verbal permission to install this valve today. After installing the valve, we will go through normal channels to request a witnessed test. Thanks Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Email DMarloweahilcorp.com Hilcorp A Company Built on Energy From: Dan Marlowe Sent: Friday, August 2, 2019 8:49 AM To: Schwartz, Guy (guv.schwartz@alaska.eov) <guy.schwartz@alaska.aov> Subject: NCIU A-02 PTD 168-091 I will give you a shout to discuss this one this morning Permit should arrive at your office before loam today Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Email DMarlowe(,a)hilcorp.com Hilcorp A Company Built on Energy The information contained in this e-mail message is confidential information intended only for the use of the recipient($) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Well Name Pre 2008 Survey Location NAD27 ASP 4 Northing Easting Post 2008 Survey Location NAD27 ASP4 Northing Easting Distance Moved NCI A-01 2,586,726.69 332,100.19 2,586,726.40 332,102.26 2.09 NCI A-02 2,586,722.85 332,108.29 2,586,721.16 332,111.27 3.43 - --- NCI A-03 2,586,728.60 - 332,106.22 - 2,586,728.31 332,109.43 3.22 _ _ NCI A-04 _ 2,586,719.62 332,105.09 __ 2,586,718.58 _ 332,108.09 3.18 NCI A-05 2,586,725.55 332,110.17 2,586,725.14 332,111.79 1.67 NCI A-06 2,586,719.66 332,102.09 2,586,719.22 332,104.19 2.15 NCI A-07 2,586,727.79 332,103.73 2,586,728.78 332,105.40 1.94 NCI A-08 2,586,720.56 332,098.31 _ 2,586,722.44 332,101.65 3.83 NCI A-09 2,586,666.58 332,039.08 2,586,667.35 332,040.44 1.56 NCI A-10 2,586,670.21 332,040.91 2,586,673.71 332,044.17 4.78 ------ NCI A-10A 2,586,670.21 332,040.91 _ 2,586,673.71 332,044.17 4.78 -_ NCI A-11 _ __ - 2,586,670.23 _ 332,039.14 2,586,677.01 -- 332,041.75 7.27 NCI A-12 2,586,722.73 331,947.80 __ _ 2,586,723.59 _ 331,994.15 _ 46.36 NCI A-13 2,586,734.88 331,993.50 2,586,733.15 331,995.48 2.63 NCI B-01 2,586,730.03 331,999.80 2,586,723.04 331,998.16 7.18 NCI B-01A 2,586,730.03 331,999.80 2,586,723.04 331,998.16 7.18 NCI B-02 _ 2,586,731.14 331,999.29 2,586,729.60 332,001.86 3.00 NCI B-03 2,586,731.69 331,986.37 2,586,726.81 331,991.70 7.23 NCI B-03P61 2,586,731.69 331,986.37 2,586,726.81 331,991.70 7.23 ~~~N~~ APR ~ 4 2008 /~`~' U°~ • r: REV DATE BY CK APP ESCRIPTION REV DATE BY CK P DESCRIPTION 1 2/29/08 $A$ 1(Vy/.! MODIFY WELL HOUSE SCHEMATIC, SHT.2 ADD MUD LINE ELEV., SHT.3 g9 g ~ 36 31 T 12 IV 31 32 ~; z ~~ n ~ 1 6 y~': T 11 N 6 5 N ,~, Ao N s. ro'u' M SEC. 6 1206' SCALE: I"=1320' --6 ~ ~ o ~ ~ 1 6 I 6 5 12 7 ~ 8 GENERAL NOTES: ~~~~ ~F q~ ~\~, ~•~~~.~ ~ 1. SEE SHEET 3 FOR COORDINATE TABLE '~P •'••• ~~''~`S~r-~1 i ~ •••• ' • . 2. SEE SHEET 3 FOR NOTES ON HORIZONTAL AND ~ •° ~ ~j ~ . ~ '~ • VERTICAL SURVEY DATA 49th ~ ~j ~ d 3. SECTION LINES AND TIES ARE BASED ON PROTRACTED ~""''"""""""""""""""""'""" j VALUES. ~. ................................ .....~ ~•~"~, ~; KENNETH W. AYERS ;~ ~, J'I ~'•., LS-8535 ~.•'• ~,~~ SURVEYOR'S CERTIFICATE • ,,~ A • I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED ~+ A'OFESSIONA~~P~~~ AND ~~~,""~~~ LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL LOUNSBURY DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF & ASSOCIATES, [NC. FEBRUARY 28, 2008. SURVEYORS ENGINEERS PWNNERS ~ v`~ PHONE: 1907) 272-5451 ~ AREA: MODULE: UNIT: ConocoPhilli s NORTH COOK INLET p TYONEK PLATFORM Alaska, Inc. WEEE CONDUCTOR AS BUILT CADD FILE N0. DRAWING N0: PART: REV: 08-005 AS BUILT 02/27/08 08-005 /~S BURET 1 of 3 1 REV DATE BY CK APP SCRIPTION REV DATE BY CK DESCRIPTION 1 2/29/08 SAS KWA MODIFY WELL HOUSE SCHEMATIC, SHT.2 ADD MUD LINE ELEV., SHT.3 .i. .'T g g r °s; a ,~8 9 s°s~ ~ AA9 TYN R9 !SO s. 9v' ~i7` SE 6 ~~ / O ~~ ~iS SCALE: I"-30' a9 RA D 600 50 - ES ESD 600-51 A13 • ~p fiz ~ AB A•A• 63.. 05 A6~ 6 ••A5 A4• 2 WELL HOUSE 2 'p O ~ z p A1O~ LEGEND: p p5 ~ 3 A ~ WELL p WELL CONDUCTOR 0 ESD (EMERGENCY SHUT OFF VALVE) GENERAL NOTES: I. SEE SHEET 3 FOR COORDINATE TABLE 2. SEE SHEET 3 FOR NOTES ON HORIZONTAL AND VERTICAL SURVEY DATA LOUNSBURY 3. NO WELLS EXIST IN WELL HOUSE N0. 4, AND IT WAS NOT & assoclATES, INC. A S B UIL T SURVEYORS ENGINEERS PLANNERS ~ PHONE: I907J 272-5451 AREA: MODULE: UNIT: ConocoPhilli s NORT" C°OK INSET TYONEK PLATFORM Alaska, Inc. W ELD CONDUCTOR AS BUNT CADD FILE N0. DRAWING N0: PART: REV: 08-005 AS BUILT 02/27/08 08-005 AS BUNT 2 of 3 1 REV DATE BY CK APP ASCRIPTION REV DATE BY CK DESCRIPTION 1 2/29/08 SAS KWA MODIFY WELL HOUSE SCHEMATIC, SHT.2 ADD MUD LINE ELEV., SHT.3 ASP ZONE 4, NAD83, FEET NAD63 GEOGRAPHIC MLLW DESCRIPTION (POINT NO.) NORTHING FASTING LATITUDE LONGITUDE ELEVATION NCIU W ELL TAG NO. WELL HOUSE NO.1 1001 2586492 1472018 61 04 34.38 150 57 03.71 72.0 Conductor 1 1002 2586489 1472017 61 04 34.34 150 57 03.72 73.9 63 1003 2586485 1472019 61 04 34.31 150 57 03.67 74.1 A12 1004 2586485 1472023 61 04 34.31 150 57 03.59 73.8 B1 1005 2586487 1472027 61 04 34.33 150 57 03.52 72.0 Conductor 5 1006 2586491 1472027 61 04 34.37 150 57 03.52 73.7 B2 1007 2586495 1472025 61 04 34.41 150 57 03.57 72.1 Conductor 7 1008 2586495 1472021 61 04 34.41 150 57 03.65 73.7 A13 WELL HOUSE N0.2 2001 2586437 1472060 61 04 33.84 150 57 02.83 71.9 Conductor 1 2002 2586433 1472059 61 04 03.38 150 57 02.84 71.9 Conductor 2 2003 2586430 1472062 61 04 33.77 150 57 02.79 71.8 Conductor 3 2004 2586429 1472066 61 04 33.77 150 57 02.71 73.4 A9 2005 2586431 1472069 61 04 33.79 150 57 02.65 71.9 Conductor 5 2006 2586435 1472069 61 04 33.83 150 57 02.64 73.3 A10 2007 2586439 1472067 61 04 33.86 150 57 02.69 73.3 A11 2008 2586439 1472063 61 04 33.87 150 57 02.77 71.9 Conductor 8 WELL HOUSE N0.3 3001 2586488 1472128 61 04 34.36 150 57 01.47 73.0 Al 3002 2586484 1472127 61 04 34.32 150 57 01.48 73.1 A8 3003 2586481 1472130 61 04 34.29 150 57 01.43 73.1 A6 3004 2586480 1472133 61 04 34.28 150 57 01.35 73.0 A4 3005 2586483 1472137 61 04 34.31 150 57 01.29 73.0 A2 3006 2586487 1472137 61 04 34.34 150 57 01.28 73.0 A5 3007 2586490 1472135 61 04 34.38 150 57 01.33 73.0 A3 3008 2586490 1472131 61 04 34.38 150 57 01.41 73.3 A7 50 2586540 1472069 61 04 34.86 150 57 02.69 72.7 ESD Valve 600-50 51 2586501 1472011 61 04 34.46 150 57 03.86 72.6 ESD Valve 600-51 100 2586572 1472123 61 04 35.18 150 57 01.58 115.3 Top center helipad -101' MUD LINE SURVEY NOTES: 1. ALL COORDINATES ARE ASP ZONE 4, NAD83, US SURVEY FEET. GEOGRAPHIC COORDINATES ARE NAD83. 2. ELEVATIONS ARE IN FEET, BASED ON MLLW, REFERENCED TO DRAWING N0. MPD- TY04-2021, SHEET I OF I, REV. 2 3. ALL AS GUILTS ARE TO THE CENTER OF EXISTING STRUCTURE. 4. WELL CONDUCTOR ARE VERTICALLY AS BUILT TO THE TOP OF A !/4" STEEL LID, TACK WELDED TO THE TOP OF THE CONDUCTOR. 5. WELLS ARE VERTICALLY A S BUILT TO THE TOP OF THE LOUNSBURY LOWEST HORIZONTAL FLANGE ON THE WELL. & nssoclaTES, INC. SURVEYORS ENGINEERS PLANNERS V PHONE: (907 272-5451 ~ AREA: MODULE: UNIT: ConocoPhilli s NORTH C°OK INSET TYONEK PLATFORM Alaska, Inc. WELL CONDUCTOR AS BUILT CADD FILE N0. DRAWING N0: PART: REV: 08-005 AS BUILT 02/27/08 ~8-~~5 AS BU~~T 3 of 3 1 ~ STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown __ Pull Tubing ,=.X 2. Name of Operator: Phillips Petroleum Co. 3. Address: P.O. Box 1967 Houston, Texas 77251-1967 4. Location of well at surface: 1256' FNL & 1089' FWL At top of productive interval: 711' FNL & 2839' FWL At effective depth: 711' FNL & 2839' FWL At total depth: 391' FNL & 4161' FWL Stimulate Alter Casing Plugging Repair Well 5. Type of Well Development x Exploratory Stratigraphic __ Service Leg 3, Slot 5 PPCo. Tyonek Platform Perforate x Other 6. Datum elevation (DF or RKB) RKB 116 Feet 7. Unit or Property Name North Cook Inlet Unit 8. Well Number Sec 6 - T11N - R9W North Cook Inlet, Ak. 4445' MD 3904' TVD Sec6- T11N- R9W 4445' MD 3904' TVD Sec6-T11N- R9W PBTD 6790' MD 5828' TVD Sec6-T11N- R9W A-02 9. Permit Number / Approval Number 68-091 10. APl Number 50-883-20018 11. Field / Pool Cook Inlet / Beluga 12. Present well condition summary: Total Depth: measured 8,429 feet true vertical 7,227 feet Effective Depth: measured 4,445 feet true vertical 3,904 feet Plugs (measured) Junk (measured) PBTD: 6,790' * 84 sx cement 7,258' - 7,415'. (see existing schematic) · Note junk at 6,790' Casing: Structural Conductor Surface Intermediate Production Liner Length Size Cemented Measured Depth True Vertical Depth 30 " Driven 385 385 16 " 825 sx CI "G 621 021 10 3/4" 1400 sx CI "G 2,637 2,420 Perforation Depth: measured 4445' - 6612' true vertical 39O4' - 5672' 1048 sx CI "G 7,189 REGESVED JAN 2 7 1995 Nast .0,1 & 6as cons. Commlssl.o.n .... , chor , Tubing (size, grade and measured depth) Packers and SSSV ( type and measured depth) 4 1/2" 12.6 Ib/ft J-55 Mod-BT&C Tubing Surface to 348' 4 1/2" 12.75 Ib/ft J-55 Mod-EUE Tubing 348' - 6626' Halliburton "XXO" SCSSV at 348' Halliburton "VSR" Packer at 4381' Halliburton "AWR" Packers at 4549', 4646', 4739 ,4993', 5100', 5383' 13. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Prior to well operation: 0 13200 Water-Bbl Casing Pressure 0.16 0 Tubing Pressure 935 04/02/94 Subsequent to operation 0 15200 2.16 10 968 12/02/94 15. Attachments: 16. Status of Well Classification as: Copies of Logs and Surveys Run__ Daily Report of Well Operations X Oil __ Gas X Suspended .m_ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed ~! jJ~,- ~~ Title Principle Engineer Form 10-404 Rev. 06/15/88 Service Date 19-Jan-95 SUBMIT IN DUPLICATE PHILLIPS PETROLEUM DAILY REPORT SUMMARY PAGE: 1 #ELL:North Cook Inlet Unit No. &-2 FIELD:COOK INLET NORTH CNTY/STATE:TYONEK OFFSHORE/ALASKA RIG:Pool Arctic Alaska/Pool Arctic Alaska AFE#:P-V125 AUTH COST:$1,639,650 DATE DEPTH RPT NO ~ OPERATIONS SUI4NARY DAILY COST CUM COST EVENT TYPE: Wo~kover 07/08/94 7,1&& 1 FINISH RIGGING DOUN & BEGIN SKIDDING FRON NCIU A-7 TO A-2 $11,566 S11,566 07/09/94 7,14~ 2 8.5 FINISHED SKIDDING RIG/KILLED WELL/SET WL PLUG/BPV/ND TREE ~0,152 S51,718 NU BOP'S/ b"Z/10/94 7,1~ .... ] 8.5 TESTED BOP'S/PULLED TEST PLUG & BPV/RETRIEVED WIRELINE PLUG/ $42,&23 '$94,141 WORKED PACKER FREE/POOH LAYING DOUN TUBING/ ~)7/11/94 "7,1~ & 8.5 FINISHED PO0tl WITH TUBING/HILL OUT & RECOVER BOTH PERNANENT S~2,3'~" PACKERS/CLEAN OUT SAND WITH BIT & SCRAPER 5980' ~REPORT TINE 07/12/94 7,144 5 8.5 FINISHED CLEANING OUT SAND/CIRC HOLE CLEAN/POOH/RIH WITH $50,153 $186,628 PERFORATING GUNS & TEST TOOLS FOR BELUGA TEST/RIG UP SCHLUHBERGER TO CORRELATE GUNS Old DEPTH 07/13/94 7,14& 6 8.5 FINISHED CORRELATING GUNS ON DEPTH/PERFORATED BELUGA SANDS/ S~8,552 $235,180 FLC)MED TO CLEAN UP/KILLED WELL/POOH WITH TEST TOOLS & SPENT/ GUNS/RIH WITH EZSV RETAINER & SET SANE AT 5400'/CIRC & CC)ND 07/14/94 7,144 ? 8.5 PERFORATED & SURGED COOK INLET/KILLED WELL/CIRCULATED OUT $171,236 $&06,416 GAS/START OUT OF HOLE WITH GUNS 07/15/94 7,144 8 8.5 FINISH LAYING DOWN TEST TOOLS & SPENT GUNS/MADE BIT & S53,612 $/,60,028 SCRAPER RUN/RUN & SET ANOTHER EZSV AT 5370'/POOH/RIH FOR DST # 3/ATTEHPT TO FLOU TEST BUT LOADED UP/RU COIL TUBING UNSUCCESSFULLY JETTED ON COOK iNLET # 11 WITH NO FLOg/POOH/ RIH WITH EZSV RETAINER & ISOLATE # 11/POOH/HU DST ASSEMBLY # 4/ 07/16/94 7,144 9 8:5 $~8,116 $508,144 07/19/94 7,144 $35,305 $78~, 233 07/20/94 7,144 S35,161' $819,394 07/17/94 7,144 10 8.5 JETTED IN COOK INLET # 9 WITH COIL TUBING & NITROGEN/FLOg $62,0~9 S570,193 SAME FOR CLEAN UP/ ~/18/94 '7,144 11 8.5 FINISHED DST # 4 OF CI # 9,KILLED gELL,POOH WITH TOOLS,BIT S178,735 S748,928 & SCRAPER RUN,TESTEO BOP'S,RIN W/EZSV RETAINER TO ISOLATE CZ ~ F/CI # 8,POOH,RIH W/DST # S TOOLS/OPEN WELL TO FLARE 12 8.5 DST #5 ON CI-8. t/ELL FLC~/ED 10.6 I~qCFG/D AT 20 B~PD. DST #6 ON CI-6. gELL FLO~/ED 1.1MMCFG/D AT 1200 BgPO, W/12 TO 15~ SANO. SET EZSV ANO PREPARE TO TEST CIo5. 13 8.5 TOH U/BIT & SCRAP.TIH & SET EZSV ~ 4850.TOH.M/U TEST TOOLS. & PKR.TIH.OST#7 ON CI'5(4800'&821).KILL gELL.L/D TOOLS.BIT & SCRAP TO 4850.TOH.TIH.SET EZSV ~ 4721.TOH.P/U TEST TOOLS.TIH 07/21/94 7,1/~J~ 14 8.5 DST #8(CI'3).KILL gELL.L/D TOOLS.TOH.TIH & SET EZSV ~ 4650. $136,173 S955,567 TOH.P/U TOOLS FOR DST #9(CI'2).TIH.DST #9.HOVE PACKER TO 4442.DST #10(CI'2 & CI'I).KILL WELL. 07/22/94 7,144 15 8.5 KILL klELL.TOH.L/D TEST TOOLS FRON DST IO.P/U BIT, 3 JUNK $40,721 S996,288 BASKETS & 9 OC.TIH.DRILL EZSV a 4650.TIH TO 4721.DRILL EZSV a 4721.TIH.DRILLING EZSV a 4850. 07/23/94 7,144 16 8.5 DRILL EZSV AT 4850.TIH TO 4960.SWEEP & CBU.TOH.CLEAN JUNK $66,791 S1,063,079 BASKETS & CHANGE BIT.TIN TO 4960.DRILL EZSV a 4960.TIN TO 5085.DRILL ON EZSV.NO PROGRESS.TOH.EMPTY JUNK BASKETS.BIT OK 07/24/94 7,144 17 8.6 TIH.DRILL EZSV a 5085.TIH TO 5176.SWEEP & CBU.TOH.TIH W/CSG $&7,179 S1,110,257 SCRAP TO 5176.CBU.TOH.P/U TEST TOOLS FOR DST 11 ON CI-9.TIH TEST EQUIP.DST 11.S/1 & REPAIR WASHOUT.DST 11.KILL WELL. 07/25/94 7,144 18 8.6 KILL 1dELL AND STOP FLUID LOSS.TOH.WEEKLY BOP TEST.P/U BHA & $~2,098 S1,152,355 TIH.CLEAN OUT 45 FILL.ORILL EZSV ~ 5176.RIH.CLEAN OUT 90 FT. FILL.DRILL EZSV a 5370.TIH TO EZSV ~ 6618. 07/26/94 7,144 19 8.6 DRILL EZSV a 6618.WASH,REAM & PUSH REMAINING JUNK TO 6806'. S38,472 S1,190,827 SWEEP & CBU.TOH.P/U TEST STRING.TIN.TAG UP g 6270 W/TAIL PIE 5140 W/PKR,L/D SANE, RIH W/BIT-J/B-CSG SCR.NO TITE SPOTS. ~/27/94 7,144 20 8.6 TEST STRING S/O W/PKR @5140.TOH.P/U ~" WATERMELON MILL,TOOLS $37,793 Sl,228,620 TIH.REAM TIGHT SPOT FRON 5140-5158.TIH TO 6790.CBU.TOH.TIH/W TEST STRING.DISP TBG.NO FLOg. R/U COILED TBG.JETTING ON gELL 21 8.6 KICK I/ELL OFF WITH N2 & COILEO TBG.R/D COILED TBG & RIG UP TEST TREE.TEST EGUIP.OPEN WELL.DST # 12.UNSEAT PACKER KILL WELL TOH. TIH WITH BHA TO CLEAN OUT FOR COMPLETION. 07/28/9~ 7,1~ s74,o2o $1';$02,640 PHILLIPS PETROLEU~ DAILY REPORT SUMMARY PAGE:2 WELL:North Cook Inlet Unit No. FIELD:COOK INLET NORTH CNTY/STATE:TYONEK OFFSHORE/ALASKA RIG:Pool Arctic Alaska/Pool Arctic Alaska AFE#:P-V125 AUTH COST:$1,639,650 DATE DEPTH RPT NO I~ OPERATIONS SUHMARY DALLY COST CUN COST 07/29/94 7,144 22 8.6 CIRC & St~EEP.TOH.L/D BHA.R/U CASERS.SAFETY & PLANNING NTG. $100,456 $1,403,096 RUN & SET PKR ASS #1.TOH.TIH g/ASSY #2.SET PKR.TOH.TIH g/ ASSY #3. SET PKR. TOll. 07/30/94 7,144 23 8.6 TOH.P/U PKR #4.TIH & '~ET ~ 4739.CBU.YOH.P/U PKR #5.TIH g SET $34,441 $1,437,537 ~ 46~6'.TON.P/U PKR #6.TIH & SET ~ 4549'.TON.P/U PKR #?.TIH & SET g 4381*.TEST ANNULUS.OK.TOH.P/U PBR.PREPARE TO RUN TBG 7,144 24 8.6 RUN 4 ~/2 TBG TO $URFACE.SPACEOUT.INSTALL 70/30 GLYCOL-KCL $~6~,'70~ $1,702,245' IN ANNULUS.HANG OFF.SET BPV.N/D BOPS & RISERS.INSTALL & TEST 3H TREE.R/U COILED TBG.RIH U/SAgE TO JET HELL IN. 7,1/,4 25 8.6 JET k'ELL IN FOR PROOUCTION.FINAL RATE · 8530.il #CF/D.SHUT $99,574 $1,801,819 t/ELL IN.R/D TEST LINES.TURN NELL OVER TO PROOUCTION AT 1159 NRS 7-31-9&. 07/31/94 08/01/94 10/30/94 7,144 26 8.6 TIH g/GUAGE RING & SHIFTING TOOL CHECKING SLEEVES. ALL $1,000 $1,802,819 SLEEVES k'ERE CLOSED. BELUGA ZONE PROOUCING. TURN klELL TO PROOUCTION. DAYSUH.RP1 i2/07/94 Gas Cons. C;ommiss~o~ Anchor~. ~ PBTD 6790' 621 2634 otis "VSR' packer ~ 4381' Cook Inlet Sands Packer ~ 4549 4445 - 4488 4495 - 4.535 4554 - 4630 Packer ~ 4646 4656 - 4670 Packer {~ 4739 4800 - 4621 (C~-5) Packer ~ 4993 Packer ~ 5100 5047 - 5059 5120-5142 5238 - 5252 Packer ~ 5383 Beluga Sands 5504 - 5510 5522 - 5527 5628 - 5632 5676 - 5680 5702 - 5708 5715 - 5730 5798 - 5808 ** 5855 - 5862 5879 - 5888 5940 - 5945 6002 - 6011 ** 6082 - 6090 6140 - 6146 6176 - 6203 6260 - 6286 6412 - 6430 6602 - 6612 Junk at 6790' ./'~ FINAL WELL COMPLETION ~ BPV(, .i,Type,OD) FMC OCT Tbg. Hgr.(Make,Type) FMC 4 1/2" 8rd X 4 1/2~' BT&C RKB-Drill Declc RKB-THF: 40.20 RKB-SL: 116.00 Annulus Fluid: 8.5 lb/gal KCL CompleUon Fluid with 30 % Methanol TOC: 3900' per CBL dated 12/13/68 WATER DEPTH: Production Casing: 120 ' RKB-ML: 40 385 40 621 651b/fl H-40 1540 630 40 2,634 45.5 & 51 Ib/fl J-55 BT&C 3350 1970 40 80 26 ib/fl 3-55 BT&C 4660 4080 g0 6,659 23 ib/fi 3-55 BT&C 4080 3080 6,659 7,189 26 Ib/fi 3-55 BT&C 4660 4080 39 348 12.60 Ib/fl 3-55 Mod BT&C 4730 4980 Note: 348 6,626 12.75 Ib/fl 3-55 Mod EUE 8rd 4730 4980 0.00 40.20 40.20 0.65 40.85 10.13 PRODUCTION TUBING STRLNG Elevation Hanger FMC / OCT 6" 3M Tubing Hanger 4 1/2" BTC Pup 3t 3.990 50,98 297.74 4 1/2" BTC Tubing 348.72 2.45 Halliburton "XXO" $CSSV Nipple 351.17 29.33 4 1/2" EUE Mod 8rd Tubing & X-Over 380.50 3990.47 4 1/2" EUE MOd 8rd Tubing 4370.97 8.70 Halliburton Upper "PBR" Assembly 3.813 3.813 4379.67 2.60 Ratch Latch Seal Unit 3.990 4381.15 6.48 Halliburton "VSR" Packer 3.880 31.32 4 1/2" EUE MOd 8rd Tubing 3.990 4418.95 1.43 Halliburton "X" Landing Nipple 3.813 4420.38 118.96 4 1/2" EUE MOd 8rd Tubing 3.990 4539.34 4.20 Hallibmton "XD" Sliding Sleeve 3.813 4543.54 4.12 4 1/2" EUE MOd 8rd Tubing 3.990 4547.66 2.60 No Go Seal Unit 3.990 4549.14 4.10 Halliburton "AWR" Packer 4.000 4553.24 5.50 Mill Out Extension 4.270 4558.74 0.65;TubingAdaptor 4559.39 10.10 4 !/2" EUE 8rd Pup Jt 4569.49 8.13 4 1/2" EUE 8rd Pup Jt 4577,62 59.19 4 1/2" EUE Mod 8rd Tubing 4636.81 4.20 4641.01 4.12 4645.13 2.60 4646.61 4.10 4650.71 5.50 4656.21 0.65 4656.86 10.12 4666.98 6.08 4673.O6 31.26 4704.32 4.20 4708.52 29.90 4 1/2" EUE 8rd Pup Jt 3.990 3.990 Halliburton "XD" Sliding Sleeve 3.813 3.990 No Go Seal Unit Halliburton "AW'R" Packer 4.000 Mill Out Extension 4.270 Adaptor 3.990 4 1/2" EUE 8rd Pup Jt 3.990 4 1/2" EUE 8rd Pup Jt 4 1/2" EUE Mod 8rd Tubing 4738.42 2.60 4.10 Halliburton "AWR" Packer Hallibmton "XD" Sliding Sleeve 3.813 4 1/2" EUE 8rd Tubing 3.990 No Go Seal Unit 3.990 4743.64 5.50 Mill Out Extension 4.270 4749.14 3.990 0.65 4749.79 242.54 4 1/2" EUE Mod 8rd Tubing 4992.33 2.60 No Go Seal Unit 4993.45 4.10 Halliburton "AWR" Packer 4.000 4997.55 5.50 Mill Out Extension 4.270 '0.65 5003.70 60.23 4 1/2" EUE MOd 8rd Tubing 4.22 "XD" Sliding Sleeve 5068:15 31.30 4 1/2" EUE 8rd Tubing 3.813 5099.45 2.60 No Go Seal Unit 3.990 5100.57 4.02 Halliburton "AWR" Packer 4.000 5104.59 5.56 Ivfill Out Ext~sion 4.270 5110.15 0.62 Tubing Adaptor 3.990 5110.77 271.98 4 1/2" EUE MOd 8rd Tubing 3.990 5382.75 2.62 No Go Seal Unit 3.990 5383.87 9.61 Halliburton "AWR" Packer & Mill Out Extension 4.000 5393.48 156.76 4 1/2" EUE 8rd Mod Tubing & Tubing Adaptor 5550.24 4.22 Halliburton "XA" Sliding Sleeve 5554.46 1069.37! 4 1/2" EUE Mod grd Tubing 6623.83 1.51 Hallibu~on "XN" Nipple 6625.34 0.66 t Guide 6626.00 End of Tubing 3.813 3.725 All depths based on drill pipe measurement~ Subtract 6 ft. to correct to wireline measurement. PRODUCTION PERFORATION INTERVALS COOK INLET SANDS "Uppa~' BELUGA SAND (cont.) C1-1 4445 - 4488 5504 - 5510 4495 - 4535 5522 - 5527 CI-2 4554 - 4630 "Middle" CI-3 4656 - 4670 5628 - 5632 CI-5 4800 - 4821 5676 - 5680 Cl-6 4886 - 4904 5702 - 5708 Cl-8 5047 - 5059 5715 - 5730 CI-9 5120 - 5142 5798 - 5608 C1-11 5238 - 5252 ** 5855 - 5862 5879 - 5888 5940 - 5945 6002 - 6011 ** 6082 - 6090 6140 - 6148 6176 - 6203 6260 - 6286 6412 - 6430 6602 - 6612 ** New Perfs TOC 7258 7" @ 7189' PBTD: 6790 Isupv: ]Tbg Wt: 4 1/2" - 12.6 & 12.75 Ib/fl Well: North Cook Inlet Unit No. A-02 November 4, 1994 TD = 8,429' Location: Alaska Field: Cook Inlet Unit MPG PHILLIPS PETROLEUM HOUSTON, TEXAS 77251-1967 BOX 1967 EXPLORATION AND PRODUCTION GROUP COMPANY BELLAIRE, TEXAS 6330 WEST LOOP SOUTH PHILLIPS BUILDING Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive AnchOrage, Alaska 99501 June 30, 1994 North Cook Inlet Unit "A-02" Phillips Tyonek Platform "A" · North Cook Inlet, Alaska Re: NOrth Cook Inlet Unit A-2 Workover Program Attached are three copies of the Application for Sundry Approvals, form 10-403, and three copies of the tentative workover program for the workover of the A-02 well on the North Cook Inlet Unit. Included in the program are the BOP schematic and the well control policy for the workover. If you have any questions concerning this workover or need any additional information please contact Paul R. Dean at (713) 669,3502. Regards, _ · . Gill, Manager Drilling and Production Engineering CC: V. R. Chamberlain M. L. Jones (r) P.__~. Dean J.F. Mitchell Central files G~s Cons. Commiss'~on Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY AP Abandon Suspend Alter Casing wRepalr Well ram 1. Type of Request: 2. Name of Operator. Philli Co. 3. Address: 6330 W. Loop South Bellaire 77401 4. Location of well at surface: 1256' FNL & 1089' FWL At top of productive interval: 711' FNL & 2839' FWL At effective depth: 711' FNL & 2839' FWL At total depth: 463' FNL & 264' FEL Sec 6 - T11N - R9W 12. Present well condition summary: Total Depth: measured 8,429 feet true vertical 7,227 feet Operation Shutdown Plugging Time Extension Pull Tubin Variance 5. Type of Well Development X Exploratory Stratigraphic Service Leg 3, Slot 5 PPCo. Tyonek Platform Sec 6 - T11 N - R9W 4445' MD Sec 6 - T11 N - R9W 4445' MD Sec 6 - T11 N - R9W PBTD 7144' MD North Cook Inlet, Ak. 3904' TVD 3904'TVD 6121' TVD Plugs (measured) Effective Depth: measured 4,445 feet true vertical 3,904 feet Junk (measured) Reenter Suspended Well ~ Stimulate Perforate Other 6. Datum elevation (DF or RKB) RKB 116 7. Unit or Property Name North Cook Inlet Unit Feet 8. Well Number A-02 g. Perm~N~.m~l~r,/Approval Number 10. APl Number ! 50-883-20018 11. Field / Pool Cook Inlet / Beluga PBTD: 7,144' 84 sx cement 7,258' - 7,415'. (see existing schematic) Casing: Structural Conductor Surface Intermediate Production Liner Length Size Cemented Measured Depth True Vertical Depth 30" Driven 385 385 16" 825 sx Cl "G" 621 621 10 3/4" 1400 sx CI "G" 2,637 2,420 7" 1048 sx CI "G" Perforation Depth: measured 4445' - 6612' JUL -5 1994 true vertical 3904' - 5672' Aisska 0il & Gas Cons. Commission Anchoraoe Tubing (size, grade and measured depth) 4" 10.9 Ib/ft J-55 BT&C & 3 1/2" 9.2 IbTft J-55 BT&C set at 5,432'. Packers and SSSV ( type and measured depth) Brown "H 1 -SRP" retr. packer @ 4,395'; Baker "F" permanent packers @ 4751' and 5423'.. Otis Wireline Retrievable SSSV ~ 303.33'. Descrip§on Summary of Proposal .~ Detailed Operations Program m BOP Sketch ~. 13. Attachments: 14. Estimated Date for Commencing Operations: Jul), 06r 1994 16. If Proposal was Verbally ApproVed: Oil Gas ..~ Name of Approver Date Approved Service 17. I hereby ce~t ~he~.~.s true and correct to the////"~ best of my knowledge: Signed ~_ .~,.~ ~~"¢ D.C. Gill Title Drip. & Prod. En~lr. Manager FOR COMMISSION USE ONLY Conditions of ApproVal: Notify Commission so Representative may witness Plug Integrity BOP Test Location Clearance Mechanical Integrity Test Subsequent Form Required 10 - Approved b), Order of the Commission Form 10-403 Rev. 06/15/88 15. Status of Well Classification as: Suspended IApproval No. _ Original Signed By David W, ~0hnstnn Commissioner Date 7//?/' Approved Copy SUBMIT IN TRIPLICATE Returned June 30, 1994 Houston, Texas North Cook Inlet Unit "A-2" North Cook Inlet Unit Tyonek County, Alaska Tentative Procedure ® · · · · · · · · 10. Kill well with 8.5 lb/gal KCl water / XanVis polymer. Fill tubing and annulus with 2 % kcl water. Bleed off pressures and monitor same. Close SSSV. Skid rig over Well No. 2 slot in Leg 3. Install BPV, remove XMAS tree, NU and test 13 5/8" 10M BOP equipment. Utilize a 16 3/4" 5M x 13 5/8" 10M DSA (FMC Unihead with 16 3/4" 5M BX Clamp Hub). Test the BOP equipment as per the attached "Well Control" program. Rig up to pull tubing. Release Brown "H" retrievable packer (4,395'). Pull 4 "tubing, SSSV and retrievable packer with tailpipe and seal assembly from the Baker "F" packers at 4,751' and 5,423'. Circulate out any gas from below the packer. Inspect all tubulars for "NORM" contamination. TIH with packer milling assembly. Mill over packer slips and recover both Baker "F" permanent packers. POOH. TIH with 6 1/8" bit and casing scraper for 7 "23 and 26 lb/ft casing. Clean out casing to PBTD of 7144'. Circulate hole clean and POOH. Make up and TIH with tubing conveyed perforating assembly to reperforate the existing and new Beluga Sands as follows: 5504' - 5510' 5522' - 5527' 5628' - 5632' 5676' - 5680' 5702' - 5708' 5715' - 5730' 5798' - 5808' ** 5855' - 5862' 5879' - 5888' 5940' - 5945' 6002' - 6011' 6082' - 6090' - REC IV[D 6176' - 6203' 6260' - 6286' dUL -5 1994 6412' - 6430' 6602 ' - 6612 ' Ai~sk;~ Oil & Gas Cons. Commission Anchorage ** New perforations Use Gamma Ray log to correlate guns on depth. Set packer and pressure up on tubing with nitrogen to fire guns. Unload well and flow for initial clean-up. Kill well and POOH with perforating assembly. TIH with bit and scraper and clean out well to PBTD. Circulate out gas until well is stable. 11. 12. If significant volumes of water and/or sand is produced during Step No. 8, TIH with DST tools and isolate intervals to check for water production. Make up and TIH With tubing conveyed perforating assembly to reperforate the existing Cook Inlet Sands as follows: 4445' - 4488' 4495' - 4535' 4554' - 4630' 4656' - 4670' 4800' - 4821' 4886' - 4904' 5047' - 5059' 5120' - 5142' 5238' - 5250' 13. Use Gamma Ray log to correlate guns on depth. Set packer and pressure up on tubing with nitrogen to fire guns. 14. Unload well and flow for initial clean-up. 15. Kill well and POOH with perforating assembly. 16. TIH with bit and scraper and clean out well to PBTD. Circulate out gas until well is stable. 17. TIH with DST tools and isolate each Cook Inlet member to check for water production. 18. TIH with Halliburton 7" permanent and retrievable packer assemblies with 4 1/2" tailpipe equipped as per the proposed wellbore schematic. 19. Make up Halliburton packer seal assembly onto the 4 1/2" tubing. TIH with 4 1/2" tUbing and SCSSV landing nipple. Land seal assembly into packer seal bore. Test annulus, then pull out of seal assembly and circulate 70/30 KCl / methanol packer fluid into annulus. Space out tubing. 20. Close SCSSV, install BPV, ND BOP equipment and NU and test 7 1/16" x 4 1/2" Xmas Tree. Remove BPV's. 21. Use coiled tubing (if necessary) and nitrogen to lower fluid level and get well kicked off. Unload well and allow clean up through the production testing equipment. Release workover rig to next well. NOTE: BHP at 3904 TVD is approx 1400 psi (7.0 lb/gal equivalent), somewhat less than the 8.5 lb/gal equivalent which will be used to kill the well during the recompletion phase. RECEIVED JUL --,.5 i994 A, iaska Oil & Gas Cons. Commission Anchorage NClU A-~. RISER AND BOP ARRANGEMENT I 6M ANNULAR PREVENTER 10M VARIABLE BORE PIPE RAM8 10M BLIND RAM8 DRILLING 8POOL 3 1/2' 10M PIPE RAM8 RISER 13 6/8' 1OM X 13 6/8' 6M ADAPTER 13 $/8' 6M X 16 3/4' 6M CLAMP RISER 16 3/4' 6M X 16 3/4' 6M UNIHEAD 16' 8RD X 16 3/4' 6M CLAMP HUB RECEIVED JUL --5 i994 Oil & Gas Cons. Commission Anchorage SECTION WELL CONTROL PROCEDURES This well is a category 3 well, as defined in Phillips Completion Workover and Well Control Policy. As such two barriers must be in place during nipple up and nipple down operations. For all other operations, two barriers, e.g. the BOP's, fluid column, etc. must be in place in order to conduCt simultaneous operations. The BOP equipment is 10000 psi WP Class 4 as per Phillips Well Control manual. The bottom set of rams should be 5" pipe rams, the middle set will be blind rams and the top set should be variable rams. Although the BOP is rated to 10000 psi, the riser and the wellhead are rated to 5000 psi. The BOP and choke manifold should be stump tested to 3000 psi. The BOP should be tested to 3000 psi upon nipple up and to 1500 psi on a weekly basis. The Alaska Oil and Gas Conservation Commission (AOGCC) should be notified prior to conducting BOP tests. The notification to AOGCC should be made early enough for them to witness the test if they desire. The maximum surface pressure for the well is 1057 psi. This pressure was obtained during the Bottom Hole Pressure Test of May 20, 1994. The well can be killed and stability maintained with 8.5 lb/gal fluid. Well control drills are to be conducted with each crew as per Phillips well control manual. Drills should be reported on the IADC daily drilling report and on Phillips Daily Drilling Report. This well produces from a series of very permeable sands. A small decrease in pressure at the perforations can result in very large flowrates. It is vital that good well control practices be followed during the course of this workover. Trip speed while POOH should be kept relatively slow to avoid any tendency to swab. Before any trip is made swab and surge calculations should be made based on the properties of the fluid in the hole. DO NOT exceed the running speed determined by the calculations. A detailed trip book comparing measured fill up requirements to the calculated requirements should be maintained for each trip. The cause for any discrepency between the actual and required fill up volume must be determined before continuing with the trip. ~INTAINING CO~"~ROL OF THE WELL IS OF THE UPMOST IMPORT~I~CE, TRIP SPEED IS SECOND~RY. The perforated intervals are isolated between the Brown "H" retrievable and two Baker Model "F" permanent packers, with 15 different intervals below the permanent packers that are effectively commingled at the present time and cannot be isolated. Ail of the zones presently perforated in this well can be killed with water. As a precautionary measure, a line should be ran from the annulus valves on the tubing head to supply workover fluid, drillwater, or seawater. This line can be used to supply workover fluid as discussed above or as a last resort can be used to kill the well with drillwater or seawater. Pumping drillwater or seawater through the annulus valves should be considered only in an emergency situation as these fluids could result in formation damage. RECEIVED JUL -5 ]994 Al~ska Oil & Gas Cons. Commission 20 TOG ~,~,~ ~ /'"~ EXISTING WELL COMPLETIO~"-~IAGRAM ~ ~., (M=ke,~,OD) FMC ~T ~-~iil ~c~: ~ ~.H~.~Ee,~) ~C 4 1~' ~d X 4" BT&C ~-~ 40.20 Annulus ~uid: 8.5 lb/gal ~mpletion fluid ~th ~ ~ methanol ~-SL: 116.~ ~ ~ TOC: 3~ ~ ~L dat~ 1~ WA~R DE~: 1~ ~-~: ...~ ?:~ ::::::::::::::::::::::::::: [::~ [[[~ [~ ::~:::: [~::~::~::~[f6~ ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: Pr~uction ~" 40 621 ~6" ~ 6~1 65 lb~t H-~ 1540 6~ 293 ~0 3/4" ~ ~6~ 45.5 ~ 51 lb~l J-55 BT~C 3350 1970 531 7" ~ ~ 26 lb~t J-55 BT&C ~ ~ ~7 7" ~ 6~659 23 lb~t J-55 BT~C 7" 6~659 7~89 26 lb~t 3-55 BT&C ~ ~ ~7 ~ubing S~i~ ~g: ~ 4" 39 4,~ 10.~ lb~t J-55 BT~C 3 ]~" 4~ 5~4~ 9.3 lb~t J-55 Mod EUE nrd ,, , :::::::::~:~:::::' .:~.: :.:.:: :;:~ , , , T~ ~ ~ PRODU~ON ~BINO 26 25 0.~ ~.20 El~ation 24 ~20 0.~ gMG [ ~T ~ ~ 4 ~ 8~d x 4 ' BTaG Tubin~ Haflg~t 3.476 23 ~.~ 262.47 4" 10.9 lb/ft J-55 BT&C Tubing + pu~ 3.476 4.~ 22 ~3,~ 3.~ Otis 31~" S~ ~nding Nipple 2.7~ 21 ~.~ ~77.~ 4" 10.9 lb~t J-55 BT&C Tubing 3.476 4.~ 20 4~.~ 1.85 X-~ 4"BT&Cto31~" EUE8rd 2.~ 5.~ 19 4~17 1.73 Otis 31~" ~ Nipple 2.750 atown '.-~s~' nkt 18 4~7.~ 5.74 ~mco 3 1~" ~M Man~el 2.~1 ~ ~a' 17 4393.~ 1.19 Ot~ 31~" '~olish~ Nipple" 2.750 16 4394.83 5.~ Bro~ 7" x 3 1~" H-1SP ReWi~able Pack~ 3.~ 15 43~.83 ~.~ 3 1~" 9.3 lb~t J-55 EUE 8rd Tubing 2.~ 4.5~ 14 ~.73 3.~ Otis 31~" '~O" Sliding Sl~e 2.750 13 ~73 62.~ 3 1~" 9.3 lb~t J-55 EUE ~d Tubing 2.~ 12 4746.55 1.07 Otis 31~" "~' Nipple 2.750 Gook Inlat ~nda 11 4747.62 3.~ Bak~ ~! ~mb~ 2.~1 3.~5 10 4751,~ 7.~ Bak~ 7" x 4" M~el '~' Pack~ 4.~ 9 ~ 475~ 561.~ 3 1~" J-55 Tubing and Bl~t Joinm 2.~1 3.~ 8 ~ 5319.79 3.~ Otis 2 7~" "XO" Sliding Sl~e 2.313 ~ - ~ 7 5~Z79 94.31 2 7~" 6.5 lbfft J-55 EUE ~d Tubing 2.~1 2.875 ~ - ~ 6 5417.10 0.93 Ot~ 2 7~" "~' Nipple 2.313 ~ - ~ 5 541&03 4.~ Bak~ ~1 ~mbly 2.~1 3.~5 ~ - ~70 4 5422:85 7.~ Bak~ 7" x 4" M~el '~' Pack~ 4.~ 3 5429.85 1.~ Ot~ 2 7~" "~' Nipple 2.205 2 5431.53 0.~ TIW 2 7~" P-1 Sh~ Sub 2.~7 1 543~43 End of Tubing ~e~ '~- ~' NOTE: Sh~ on Bro~ re~able pack~ ~t at 45,~ 1~. ~ 475~ ~_~ ~~1 V B~er 'F-I' PRODH~O~ PE~O~TIO~ Beluga ~nds COOK I~ET S~DS BELUOA S~ (~nt.) ~ - ~10 'Upped ~ - ~27 Cl-1 ~ _ ~ ~ - ~10 ~5 - ~ ~ - 5527 ~8 - ~2 CI-2 ~ - ~ "MiddY" ~7~ - ~ c~-3 ~ _ ~70 s7m - ~7~ c~-5 ~ - ~1 5715 - ~7~ c~-e ~ - ~ ~7~ - ~7~ 57~ - ~ CI-8 ~7 - ~ 5715 - 57~ ~79 - ~ CI-9 51~ - 51~ 5798 - ~8 ~ - ~ C1-11 52~ - ~ ~79 - 61~ - 61~ ~ - ~11 6176 - ~ ~1~ - 81~ ~2 - ~12 ~12 - ~ - ~12 "Lo~d ' ~ 7189' PBTD: 7,1~ ~ Supv: I Tbg Wt: 4 1~" - 12.6 & 12.75 lb/ft Well: North ~k Inlet Unit No. A-~ TD 429' Location: Lower Cook Ala.~ka Field: Cook Inlet Unit PRD ~i~[~'~ ~ PROPOSED WELL COMPLET"-~I DIAGRAM ~E~i~ ~.. (Ma~,~,OD) FMC ~T ' ~-~ill ~k: ~ ~,H~,~ake,~) ~C 4 1~" ~ X 4 1~' BT&C ~-~ 40.20 ~ ~nulus ~uid: 8.5 lb/gal K~ ~mpletion ~uid ~th ~ ~ Methanol ~--SL: 116.~ ~ ~ TOC: 3~0' ~ CBL dated 1~ WA~R DE~: 1~ ~-~: ~ Pr~ucti°n ~sing: ....... 16" ~ 621 65 lb~t H-~ 1540 6~ 293 4o 26 bat x&c 7" 6~659 7~189 26 Ib~t J-55 BT&C ~ ~ 327 ~bing ~i] ~ ~ 4 1~" 39 ~ 12.~ lbfft J-55 M~ BT&C 47~ 49~ 135 4 1~" ~ 6,~0 12.75 lbfft J-55 Mod EUE etd 47~ 49~ :::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::?~::~:::~?::~::~::~::::~::~::?:~::~:::~::~::~:~?:~::~:~?:~3~?~?:::~::~::~. ~::~::~ ?:~::::~?:?:~?: PRODU~ION ~BING ~ING ~ -0.~ 40.20 El~ation 31 ~.20 0.~ FMG / ~T ~ ~ 4 1~ 8rd x 41~ BT&O Tubing Hang~ 3.958 6.~ ~ "VBR" p~ker ~ ~.~ ~7.~ 4 1~" 12.6 lb~t J-55 M~ BT&C Tubing 3.958 5.563 29 ,.~ 2.50 Hallib,ton 41~" S~SV ~nding Nioole 3.813 ~ 350.~ ~.~ 4 1~" 12.6 lbfft J-55 M~ BT&C Tubing 3.958 5.563 Oook In~t ~nda 27 ~0.~ 0.75 X-~ 4 1~" M~ EUE 8rd x 4 1~" M~ BT&C 3.953 4.919 26 ~1.47 4~.~ 4 1~" 12.6 lbfft J-55 M~ E~ ~d Tubing 3.958 5.563 ~ - ~ 25 4~1.47 0.75 Otis ~tch-~h ~l Unit 3.955 5.627 ~95 - ~5 24 4~22 5.~ Ot~ '~SR" Hy~aulic ~t Rewi~able Pack~ 3.~ 5.9~ 23 4~7.50 ~.~ 4 1~" 12.6 lbfft J-55 M~ EUE ~d Tubing 3.958 5.563 = 21 ~19.07 270,~ 4 1~" 12.6 lb/ft J-55 M~ EUE 8rd Tubing 3.958 5.563 ~ - ~70 19 ~9~25 ~.~ 4 1~" 12.6 lb~t J-55 M~ EHE 8rd Tubing 3.958 5.563 :~ 4753.25 10.. Hallib,on P~anent Pack, / ~1 Bore E~. 3.958 5.563 17 476Z25 ~.~ 4 1~" 12.6 lb/ft J-55 M~ EUE 8rd Tubing 3.958 5.563 16 ~Z25 4.18 Ot~ 41~" ~" Sliding Sl~e 3.813 5.475 15 ~7.43 20.~ 4 1~" 12.6 lbfft J-55 M~ EUE ~d Tubing 3.958 5.563 ~ - ~21 14 ~7.43 10.~ Hallib~on p~anent pack~ / ~1 n~e E~. 3,958 5.56~ (Cl-5) 13 ~57.43 ~.~ 4 1~" 12.6 lb~t 3-55 M~ E~ ~d Tubing 3.958 5.56~ 12 4917.43 4.18 Ot~ 4 1~" '~" Sliding S,~e 3.813 5.475 11 4~1.61 ~.~ 4 1~" 12.6 lb/ft J-55 M~ EUE 8rd Tubing 3.958 5.563 10 4951,61 10.~ Hallib~on P~anent Pack~ / ~1 Bore ~. 3.958 5.563 9 4~1.61 ~.~ 4 1~" 12.6 lb/ft J-55 M~ E~ 8rd Tubing 3.958 5.563 8 5261.61 4.18 Otis 41~" '~" Sliding Si~e 3.813 5.475 ~ - 49~ 7 5265.79 120.~ 4 1~" 12.61b/ft J-55 M~ EUEBrd Tubing 3.958 5.56~ 5 5395.79 150.~ 4 1~" 12.6 lbfft J-55 M~ EUE ~d Tubing 3.958 5.563 4 5545.79 421 Otis 41~" "~" Sliding Sl~e 3.813 5.475 3 5550.~ 1~.32 4 1~" 12.6 lbfft J-55 M~ EUE 8rd Tubing 3.958 5.563 2 ~l&~ 1.~ Otis 41~" '~' Nipple 3.~5 4.987 ~7 - 50~ 1 ~20.~ End of Tubing 5~ - 5~42 _.., ~ ~ 52~-52~ ~ ~~! · --- ~ O~ & fins Go~s. uumm,~o PRODU~ION PE~O~TION I~ERV~8 Beluga Studs COOK I~BT S~D5 BELUGA 5~ (~nt.) ~ - 5510 'Uppee ~m - 5~7 c~-~ ~5 - ~ ~ - ~0 ~95 - ~ ~ - ~27 ~8 - ~2 CI-2 45~ - ~ 'Middle' ~76 - ~ Cl-3 ~ - ~70 ~28 - ~2 57~ - 57~ C1-5 ~ - ~21 ~76 - ~ 5715 - 57~ CI-6 ~ - 4~ 5702 - 57~ 57~ - ~ CI-8 ~7 - ~9 5715 - 57~ ~ - 5~2 CI-9 5120 - 5142 57~ - ~ ~79 - ~ C1-11 52~ - 52~ ** ~5 - ~62 ~ - 5~ ~7~ - ~ ~ - ~ 5~ - ~ - ~12 7' ~ 7180' PB~: 7,1~ ~Su~: [TbgWt: 41~" - 12.6&12.75 lb/ft Well: ~o~h ~t Inlet Hnit ~o. ~--~ [ June 29 ~ 1~ ~ation: ~r ~k lnlet~ AIas~ Field: ~k Inlet Unit P~ 10:51 MMILLIM5 I.~KILLIMO PHILLIPS PETROLEUM HOUSTON, TEXA~ ?7251-1967 80X 1967 EXPLORATION AND PROI3iJCTiON GROUP lU COMPANY eELLAIR;, TEXAS 6330 WEST LOOP SOUTH HH~LUPS BUILDING June 30, 1994 North Cook Inlet Unit 'A-02" Phillips Tyonek Platform "A" North Cook Inlet, Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive AnchOrage, Alaska 99501 Re: North Cook Inlet Unit A-2 Workovar Program Attached am three copies of the APplication for Sundty Approvals, form 10-403, and three copie~ of the tentative workover Drogram for the wnrknver nf the A-02 welt on the Nocth Cook Inlet Unit, Included in the program are the BOP schematic and the well control policy for the workover. If you have any questions concerning this workover or need any additional information please contact paul R. Dean at {71~) 669-3502. RegaEd~ ~, Manager Drilling and Produ¢~tion Engineering CC: V. R. Chamberlain M, L, Jones (r) P,__~, Dean J.F. Mitchell Central filea RECEIVED JUL O1 1994 Alaska 0it & (~as b0ns. uommis~u" Anchorage J'UL-O 1-1994 10: S2 FROM PHI LL I PS I)R ILL I N~ TO Id 1~'/:-"/b'F~4~' ' /~" STATE OF ALASKA ~"~ ALAe~OIL AND GA800NSERVATION COMMI=61ON APPLICATION FOR SUNDRY APPROVALS 1, Type oi Requ~; Abmdcm ~ Suspend .__ O~r~en Shutdown___ P, eermr empended Wal__. Vadanee Pe,~m_te O~-,,er Name of Operator: of Well Petroleum Co. Dev~o~ner~_ X 116 3. Addre~: F. xpioralury ..... ir. un/l or Property 6aao w, Loop 8outh Stratigraphlo Nortt~ Cook Inlet Urdt 77401 ~e ~'~11 a I~,;i~e: Leg 3, ~ot 5 PPCo. Tyonek Pla~orm I~'FNL & I~~ ~G-TtlN-~W ~nh~Klnlet,~. ~ p~~ inte~: ~' MD 3~' ~ 711'FNL& ~'~ ~e-T11N- ~~ ~: 4445' MD 3~' ~D 711'FNL & ~'~ ~G-T11N-ReW At~~: P8~ 71~' MD 6121' ~D FNL & ~4'FEE ~6-T11N-~W well ~~n ~~: De~: ~md 8,4~ fu~ Plu~ (me~re~ true ~ 7,~ f~t Effeceve De,h: measured 4,445 feet . Junk (measurec~ l~ue verlk;al 3,904 feet 8, Well Number A-02 9. Permit 10, APl Number 50--883-~0018 PBTD: 7,144' a4 ax cement 7,2i~8' - 7,41 (see existl~ ~metb) Intermed~te Pro~uctk)n Length 5~ oememea 30 · DrNen t6 · 825 ~ Gl t 0 8/4' 1400 ~x CI Measured Oep~ True Ver~c~ Dep~ 385 621 621 2,~r 2,420 7' 1048 ax CI 'G' 7,189 Perforation Depth: mea,.~ured 4446' - 6612' true vertical Tubing (~i,t:e, g, aclu and measurea oepm) Paokers mM ~K)SV ( type ancl measurea aelxn) 13. ARac~n~: °""RECEIV D JUL 01 14. E~mated Date for Commencing O~ratlons~ 16. ff Propo~ wa~ Verbally Approved; 15. Status of Well Cl~.~~n as: ,~rv~e ~ knovdedge: Name { Date: lt. m hereby ceri~/.~~~.e, j~,m true anti corrmt to S .~.n, ,e~,.~, ~ ~ p,~G. Gill Tee Orlg, & Prod: ~Engr. Ma .r!a_ger ,,~ FOR COMMISSIOn' UffiE ONLY ...... Plug Integrity BOP Test Location Clearanoe__ Meonaneas Imegr~y TeSt subsequenlFormReqt~red 10 -/-/0/~ .... ^¢q~roved by Order of. the Oomm~ From tO--4Oa Rev. G6~'IS/~J ....... -ORIGINAL SIGNED BY 'RUSSELL A. DOUGLASS" ..... ,,~m~..~ner ~,_~e._ 7--/- ? ¥ '- ' SLIBI~IT. IN TRII~I~XTI~ Approved Copy Returned .... IU 30, 199~ HoustOn, ~exas North cook Inlet Unit North Cook Inlet Unit Tyo~ek County, Alaska Tentative Procedure . 2~ . 4~ . 6~ · 9. 10. Kill well with 8.5 lb/gal KCl water / XanVis polymer. Fill tubing and annuluB with 9 % ko1 water. Dleed off presuur~ and monlcor same. Close $SSV. Skid rig over Well No. 2 slot in Leg 3. Install BPV, remove XMAS tree, NU and test 13 5/8" 10M BOP equipment. U~£1tse a 16 3/4" 5H XthlJ 5/8" 10M DSA (FMC Unlhead with 16 3/4" 5M BX Clamp Hub). .Test BOP equipment as per the attached #Well Con~rol# program. Rig up to pull tubing. Kelease Brown "H" retrievable packer (4,395'). Pul! 4 "tubing, $SSV and retrievable packer with tailp~pe and s~al assembly from th~ Baker "F" packers a~ 4,751~ add 5~423~. Circulate out any gas from below the packer. Inspect all tubulars for "NORM" cont~amlnation. TrH with packer milling assembly. Mill over packer slips and recover both Baker "F' permanent packers. POOH. TIH with 6 1/8" bit and casing scraper for 7 "23 and 26 lb/it casing. clean our oas~ng ~o PBTD of 7144~. Circulate hole clean and POOH. Hake . up and TIH . w~th tubing conveyed perforating assembly ~0 reperforate the existing and new Beluga Sands as follows: 5504~ - 5510' 5522~ - 5527' 5628' - 5632' 5676' - 5680' 5702~- 5708~ 5715' - 5730* 5798~ - 5808' · * 5855' - 5862~ 5879~ - 5888~ 5940' - 5945 6002~ - 6011. ** 6082' - 6090 6140m - 6148 6176~ - 6203 6260' - 6286 6412~ - 6430 6602' -. 6612 New perforation~ RECEIVED JUL O1 1994 Alaska Oi~ & ~as uons. uommi~m' Anchorage Use Gamma Ray 1oo to Correlate guns on dept~h. Se= packer and pressure up on tubing with nitrogen to fire guns. Unload well and flow for initial clean-up. Kill well. and POOH' with perforating assembly. TIH with bit and scraper and clean out well to PBTD. Circulate out gas until well i~ ~tablo.. JUL-D1-1994 10:53 FROM PHILLIPS. DRILLIN~ ]U oz~f=~of~= ..... ~1. If ni~l~can~ ~olum~ ~f wa~= and/~ san~ ~s produced during step No. S, TIH w~th DST tools and isolate intervals to check for wa~er production. 12. Make ul~ and TiH wi~h tubing conveyed per fora=lng assembly to reperforate the existing Cook Inlet sands as follows: 444~~ - 4488~ 449§~ - 4535~ 4~54~ - 4~O~ 4656~ - 4670~ 4800* - 48~1~ 488~ - 49~4~ 5047~ - 5059~ ~120~ - 5142~ 5238~ - 5250~ 13. 14. US~ Gamm~ Ray log ~o correlate guns on depth. Set packer and pressure up on tubing with n~trogen to fire guns. unload well and flow for initial clean-up. 15. Kill well and POOH w~th perforating assembly. 16. TIH w~th bi~ and' scraper and clean out well to PBTD. Circulate out gas un~il well is stable. 17. TIH with DST tools and i~olate each Cook Inlet member to check for water production. 18. TIH with Halliburton 7" permanent and retrievable packe~. ~ssemblies wi~h 4 1/2" tailpipe equipped as per the proposed wellbore schematic. 19. Make up Halliburton packer seal assembly onto the 4 1/2" tubing. TIH with 4 i/2" tubing and SCSSV landing nipple. Land ~eal a~e~bly packer seal bore. Test annulus, then pull ou~ of seal assembly and circulate 70/30 KCl / methanol packer fluid into annulus. Space out tubing. 20. Close SCSSV, install BPV, ND BOP equipment and NU and test 7 1/16" x 4 112" Xmas Tree. R~.move BPVts. 21. Use co~l~-d tubin9 (if necessary) and nitrogen to lower fluid level and get well kicked off. Unload well and allow clean up through the production testing equipment. Release workover rig to next well. NOTE: BHP at 3904 TVD is approx 1400 psi (7.0 lb/gal equivalent), somewha~ l~ss ~ha~ the 8.~ lb/gal equlvalen~ whi~ will be used to kill the well during the recompletion phase. RECEIVED JUL 0'1 1994 Alaska 011 & 8a$ bona ~;ornmi~' Rnohorage NCIU A-c?. RISER AND BOP ARRANGEMENT eM ANNULAR PREVENTER 1OM VARIABLE BORE PIPE RAM8 1OM BLIND RAM8 DRiLLINQ 8POOL 1/2' 1OM PiPE RAM8 RISER 13 8/$' 1OM X 1~3 $/8' 8M ADAPTER 13 6/8' SM X 16 ~/4' 6M CLAMP l ' ! RISER 16 0/4' 6M X 16 0/4' 6M I I i ,, ,, ........... J NIHEAD 16" 8RD X 16 $/4' 6M GLAMP HUB RECEIVED ,JUL O1 1~94 .Oil.& Gas uons. uommJ~l~,, ~ohorago · JUL-Ol-1994 10:54 FROM WMILLIM~ and Well Control Policy. As such two barriers must ~ in place during ~i. pple up and nipple do~ operations. For a~l other operations, two barriers, e.g. the BOP~s, fluid colu~, e~c. mus~ be ~n place in order to conduct simultaneous operations. The BOP equipment is 10000 psi WP Class 4 as per Phillips Well Control manual. The bottom set of ra~s should be 5" pipe rams, the middle set will be blind rams and the tod set should be variable rams. ALthough the BOP iS rated to 10000 psi, the riser and the wellhead are rated to S000 psi. The BOP and choke manifold should be stump tested to 3000 psi. The BOP should be te~ted to 3000 ps~ upon nipple up and to 1500 psi on a weekly basis. The Alaska Oil and Gas Conservation Commission .(AO~CC) should be notified prior to conducCIng BOP tests. The notification to AOGCC should be made early enough for them to witness the test if they desire. The maximum surface pressure for the well is 1057 psi. This pressure was obtained during =~e Bottom Hole Pressure Test of May 20, 1994. The well can be killed and stability maintained with 8.5 lb/gal fluid. Well control drills are to be conducted with each crew as per Phillips well ¢on~rol manual. Drills sh°uld be reported on the IAPC daily drilling report and on Phillips Daily Drilling Report. This well produces from a series of very permeable sands. A small decrease. in pressure at the perforations can result in very large flowrates. It is vital that good well control practices be followed during the anur~e of this wo~kover. Trip speed while POOH should be kept relatively slow to avoid any tendency ~o swab. Before any trip i.s made ~wab and surge calculations should made based on the properties of the fluid in the hole. DO NOT exceed the running speed determined by the calculations. A detailed trip book comparing measured fill up requirements to the calculated requirements should be maintained for each trip. The cause for any discreDenoy between the actual and required fill up volume must be determined before continuing with the trip. MAINTAINXN~ CONTROL OP TH~ N~LL IB OF THE UPMOST XM~itTANC~, TRIP B~EBD IS ~E~ONDI~t¥, The perforated intervals are isolated between tho Brown "H" re~rievable and two Baker Model "F" permanent packers, with 15 different intervals below the pe~anene packers that are effectively commi~gled at the and cannot be Isolated. All of the zones presently perforated in this well can be killed with water. Am a precautionary measure, a line should be ran from the a~ulus valves on the tubing head to supply workover fluid, drillwater, or seawater. Thi~ llne can be used =o supply workover £1uid as discussed adore or as a last resort can be used to kill the well with drillwater or =eawater. Pumping dr~11water or ~eawater ~hrough the annulus valves should be considered only in an emergency situation as these fluids could result im formation damage. dUL O1 1994 A/a~ka 0il & ~as bo;is. , JUL-01-199,1 10:55 FROH PHILLI~ 9~1LL. H~-~ ~u ................ 1 RECEIVED ~iL 01 1994 'w Form 10-403 REV. 1-10~73 Submit "1 ntention$" in Triplicate & "Subsequent Reports. in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) OiL I'--I GAS I'~ WELLI I WELL!''1 OTHER NAME OF OPERATOR Phillips Petroleum Company 5. APl NUMERICAL CODE 50.-283--20018 6. LEASE DESIGNATION AND SERIAL NO. ADL~.lTb89 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME NCIU 3. ADDRESS OF OPERATOR 9, WELL NO. P. 0. Drawer 66 - Kenai, Alaska 99611 A~2 10. FIELD AND POOL, OR WILDCAT North. Cook. Inlet 4. LOCATION OF WELL Atsurface Leg 3, Slot 5, 1255.72' FNL, 1089.16' FEL, Sec. 6, TllN, Rgw, S.M. BHL 463' FNL, 264' FEL, Sec. 6, TllN, RgW., S.M' 13. ELEVATIONS (Show whether DF, RT, GR, etc.) RKB 116' from MLLW CheCk Appropriate Box To Indicate Nature of Notice, Re 14. 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) See. Item 4 BHL~ 12. PERMIT NO. 68-91 )orL or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT OR ACIDIZE ~ ABANDON* REPAIR WELL Clean~ CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form,) 15. DESCRIBEPROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. 1. Rig up. Kill well with. 10 ppg mud. Remove tree. I.natall 12" 3000# WP riser and 12"-3000# WP double gate preventer and Hydril. Test BOP and riser. 2. Pull 4" tbg and retrievable packer. 3. Cleanout to 7144 PBTD. . Run combination 4" x 3 1/2" tubing stri.ng with. 0ti.s subsurface safety valve set about 300 RKB and Otis retrievable packer set about 4400'. MD RKB, and tubing set 6620' MD RKB. 5. Install tree and displace mud with water. Set hydraulic packer. Test packoff. 6. Clean up well and conduct 4 Point BPT. 7. Utilize as a producer commingled in Cook Inlet and Beluga Pays. Estimated start of operations is 8/8/75. 16. I hereby certify that the/fO~o~g is true and correct SIGNED/ /_c ( ~ ~'-~''- · [ 1~.-,;. ror~er TITLE Sr. Petroleum Engineer DATE 7/15/75 (This space for State office use) APPROVED BY, CONDITIONS OF APPROVAL, IF ANY'- TITLE DATE See Instructions On Reverse Side PHILLIPS PETROLEUM COMPANY ANCHORAGE, ALASKA 99501 ~ 515"D" STREET EXPLORATION AND PRODUCTION DEPARTMENT June 26, 1989 Mr. T. R. Mzrshall, Jr. Division of Mines & Minerals Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska Gent lemen: As per your request, please find copies of blue l~ne Electrical Logs for NCIU #A-l, #A-2·~d #A-~. If at all possible these blue lines will be furnishe~ v~lth Complet.ion Reports, in the future. JBG:jo Attachment Yours truly· HILLIPS PET P~O 'LEUi'~[ ~ CO~flPANY john B. Gip~.on";~-'~ -~ -- - ~':'; District Office l~n~ger PHILLIPS PETROLEUM ANCHORAGE, ALASKA 99501 ~ 515 "D" STREET EXPLORATION AND PRODUCTION DEPARTMENT COMPANY March 18, 1969 Mr. T. R. Marshall Division of Mines & Minerals Dept. of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 9950~ Dear Mr. Marshall: As per your request, please find attached copy of Directional Survey on our North Cook Inlet, Well#A-2. Copies of surveys on future wells will be furnished your office with Well Comple- tion Report. Yours truly, JBG:Jo Attachment PHILLIPS PETROLEUM COMPANY /District Office MAnager DIVISION ~ OIL AND GRS Naech 13, 1969 Re: North CooE ]:nlet A-2 Phtlllps Petroleum Company, Operator )ar. ~lohn 13.. GSpson Otstrtct Office Hana~r Phtlltps Petroleum C(xapany 515 O Street Anchorage,. AlaSka 9~1 Dear Sir- Records tn this office show that your North Cook Inlet A-2 weit was spudded On October 28, 1968, and completed on January 11, 1969. The dlrecttonml sUrVey, as requ(:red by the drllltng permit, has not been received in this office. It is necessary that this survey be satmttted as soon as posstble so that the records in this office wtll be complete. AMERICAN STRATIGRAPHIC P.O. BOX 2127 · ANCHORAGE:, ALASKA · TRANSMITTAL COMPANY Februar~ 5; 1969 Division of Oil & Gas Attn: Mr$ Harry Kugler Dear Sir: We have transmitted this date via Personel Deliver~ cn~ Cb4.~.~ , samples from the: Phillip - A-2 Cook Inlet Core Chips #1 - #8 ( 10 B oxes ) Please acknowledge receipt by returning one copy of ~his transmittal. Very truly yours, Ronald O. rockway American Stratigrapt/ciaO o. Receipt acknowledged by date Remarks: Form No. P---4 REV. 9-~0-67 STATE OF ALASKA OIL AND GAS CONSERVATION COMMIYrEE SUBMIT IN DUPLICATE MONTHLY RE!PORT OF DRILLING AND WORKOVER OPERATIONS 1. OIL [---] GA~ ~ OTHER WW.LL WELL 2. NAME OF OPERATOR Phil ] ~ps Petroleum Company 3, ADDRESS OF OPERATOR 515 "D" Street, Anchorage~ AlaSka 4. LOCATION OF WELL 99501 Leg 3, Slot 5, North Cook Inlet Unit, Platform Tyonek, 1255.72' FNL, 1089.16' FWL, Sec. 6, TllN, R9W, S.M. ,,/9/69 5. AP1 NUAiERICAL CODE 50-283 -20018 6. LEASE DESIGNATION A%'D SESqlAL NO. ADL-17589 7. IF INDIA]~, ALOI il~]~ OR TRIBE NAME 8. U~NIT,FA-RM OR LEASE NA~ME NgFth Cook Inlet Unit 9. WELL N'O. 10. FL~UD AND POOL. OR WILDCAT North Cook Inlet 11. SEC., T., R., M.. (BO'I'TOM HOLE oB,rmCT~ · Sec. 6, TllN, R9W~ S.M. 1~. PERMIT NO. 13. REPORT TOTAL DEPTH AT END'OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH AND ANY OTHER SIGNIFICANT CHA~-GES IN HOL]~ CONDITIONS. Fish for Baker Recorder. Recovered 30" of recorder. 1 O 19S9 Drilled 9-5/8r' hole to 8429'~ (Cored 6388, -6437') Di¥1SlOHO[O'LA"OGA$ Set cement plug (8429' - 7258t) 84 sx Class G cement w/2% CaC12 Set 7" casing @ 7189.36' RKB, cemented 1st Stage w/428 sx Class G cement, cemented 2nd Stage w/620 sx Class G cement. Top of cement 5196'. Drilling out cement. PBTD Perf. 6602' - 6612' and 6412' - 6430'. Test Interval #1 thru 40/64" choke, rate 1045 MCFD, F.T.P. 1900 PSI. Test on 46/64" choke, rate 3700 MCFD, F.T.P. 1510 PSI. Perf. 6240' - 6248', 6176' - 6203', 6260' - 6286'. Test Interval #2 en 3/8" choke, rate 6450 MCFD, F.T.P. 1935 PSI. Test on 1/8" choke, rate 750.~MCFD, F.T.P. 2100 PSI, Left Baker Recorder in hole. Perf. 5504'-5510', 5522'- 5527', 5628'- 5632', 5676'- 5680', 5702'- 5708', 5715' - 5730', 5798'.- 5808', 5879' - 5888', 5940' - 5945', 6002' - 6Ol1'. Test Interval #3 on 3/8" choke, rate 59&5 MCFD, F.T.P. 1865 PSI. On 5/8" choke, rate 8567 MCFD, F.T.P. 1400 PSI. Perf. 5047' - 5059', 5120" - 5142', 5238' - 5250'. Test Interval #4 on 3/8" Choke, rate 6758 MCFD, F.T.P' 1865 PSI. Perf. ~886' -~90~', 48001-~4821'. Test Interval #5 on 3/8" choke, rate 5189 MCFD, F.T.P. 16OO PSI. Perf. 4670' .-~656', 4630, -&554', 4535' -h495', ~88' -~h45'. Test Interval #6 on 3/8" choke, rate 5475 MCFD. F.T.P. 1500 PSI. On 1/8" choke, rate 581 MCFD. F.T.P. 1562 PSI. On 3/16" choke, rate 133~ MCFD, F.T.P. 1540 PSI. On.~", rate 8350 MCFD, F.T.P..12~O PSI. On 3/~" choke, rate 16,950 MCFD, F.T.P- 1085 PSI. 14. I hereby ce~ify th~ th~ Ioregoin~is tl~? ~ 1 -mm ( /~~~~ Office ~~.r nA~ 45n~ 9. 1969 /- - - . ~TE~Report on t~is form is required for ~a[h ~ale~ar md,th, regardless of the status of operations, an~ must ~ til~ i~ g~plicat~ ~ t~e Division of Mines & Minerals by the lSth of t~e succeeding month, unless othe~ise directed. Form No. P--4 STATE OF ALJ~SKA OIL AND GAS CONSERVATION COMMI'i-i'EE MONTHLY REPORT O'F DRILLING AND WORKOVER OPE:RATIONS 1. OzL ~ G~ r~l 2. N~E OF OP~T~ . P~~s Pet.r~le~ ~m~ 515 "D" Street. l~chora~e, SUBMIT IN DUPLICATE Alaska ,,, 99501 Leg 3, Slot 5, N~h Cook Inlet Unit, Platform S.M. 1255.72' FNL, 1089~' FWL, Sec. '6, TllN, RgW, Tyonek, DIVISION OF OIL AND GAS ANCHOgAGE "s. A~'I N~mmCAL boDE 5,0-283-20018 LEASE DESIGI~ATION A.N'D SERIAL NO. ADL-17589 t. IF INDIAN, AL,OTTEE OR TRIBE NAME / 8. U'NIT,FA.RM OR LEASE NAME / North 0ook Taler 9. WELL .~O. / #A-2 ,~ 10; FIELD A.ND POOL. O/~VILDCAT . North aonk ~la~ , , Il. SEC., T.. 1~., M.. 0~O~FOM Sec. 6, ~, ~, s.M. 13. REPORT TOTAL DEl'TH AT END O~MONTH, CHANGES IN HOLE SIZE. CASING AND CEMENTING ,~OBS INCLUDING DEPTH SET AN~ VOLUMES USED, PERFORATIONS, TESTS AND RESULTS, FISHING JOBS. JD-NK INHOI.,~ 2~ND SIDE-TRACKED HOLE AND ANY OTKEtt SIGNIFICA2qT CI~ES IN HOLE CONDITIONS. ~./ · , 12/31 Fish for r Recorder. Recovered 30[ or'recorder. 12/1-12/8 Drilled 9-5~" hole to 8~29'. (Cored 6388, -6~37' ). 12/8-12/9 Set cement pl~!SA29,. - ?258' ) 8~/~x Class G cement w/2% 0a012 Set 7" casing @ 7~89.36' RKB, Ce~nted 1st Stage w/~28 ax Class G cement, cemented 2nd Stage~/620 sx Cla~s G cement. Top of cement 5196'. Drillinz out cement. PBTD 7~'o / - 6~2i- 6~30'. Test .Interval #1 thru ~0/6~" choke, rate 10~5 HCFD, .F.T.P. 1~ PSI. Test on ~6/6~"'choke, rate 3700 MCFD, 3/8" choke, rate 6~50~CFD, ~.T.P. 1935 PSI. Test on 1/8,' choke, rate 750.~MCFD, F.T.P. 210~PSI. Le~ Baker Recorder in hole. Perf. 550~'. 5510'/5522' -5~7', 5628'- 5632', 5676'- 5680', 5702'- 5708', 5715' - 573~i, 5798' - 58~8', 5879' - 5888', 6002' - 6011'. T~t Interval #3 o~3/8" choke, rate 1865 PSI. On 5/~' cho~e, ~te.8567~FD, F.T.P. 14OO P~I. Pe~rf.. 50~7' -%059', 5120' - 5142', ~238' .-. 5250'. Test. Interval #~ on 3/8" choke, ~te 59~5 MCFD, F.T.P. 18~ PSI. On 5/8" choke, ~ate 8567 MCFD, F.T.P. i~O0/PSI ..... k , '. I ' 5189 ECF~,,F.T.P. 1600 PSI, ,,-,.,. ;..,..~, / ' Fa_.te~8m ~CFg, F.T.P. 1562 PSI. On I/Z6" cho~, rate 133~.AO~D, F.T.P. 14. I hereby certify that the/oregoing l~ true and correct / \ SIGNED ,. ./ , . , TITL~ DAT~ J J J _.. I II I,,1 1~ mr J NOTE--Report on this form Is required for each calendar month, regardless of the status of operations, an~ must I~ fileJ in duplicate with the Di~sion of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. ,~WELL COMPLETION QR.RECO~I~TI~N'iREPORT AND LOG , WELL i i WELL [~1 VR~ ~ Othe~ ' b. TYPE 0F COMPLE~ON: OVER ~ DEEP' WELL ~. NAME OF OPERATO~ a ADDRESS OF OPERATOR ' ..... SUBMIT IN DUPLICAllS* STATE OF ALASKA {See other In- struct ions on OIL AND GAS C:ONSER~.AnO~i,~OMMITTEE ! r.,,e,-~e s,a., 515 'D" Street, ~nchor&ge, Alaska LOCATION OF ~ELL ~eport {oca~ton clearly and i~'acco~dance ~t ,,~ac~ ~g 3, Slot 5, North Cook ~et ~, ~Piatfo~ "Tyonek" reporte8 below ' F~, 2839' m~m, Sec. 6, T~,.-:Rg~I; ~$.M. t total dep~ ks3, F~m, ~8~, ~, Sec. ~, T~}~, 5. APl N~C.~L CODE 50-283-2901.8 'L LE/kSE DESIGN&TION A~D SERIAL NO. ADL-17589 IF LNI}IA~I, AZ~LO~ OR TRIBE NA1VI~ B. UNIT,FArM OR LF, ASE NAME . i',Io~h Cook Inlet Unit 9. WELL NO, '10. 11, ~A-2 , FII~,D ~ POOL; OR WI'LDO~T - North CoOk Inlet s~., T,,' A.: ~.: (m:n-ro~ Sec.. 6, T~N, Rgw, S.M. 12. P~MIT NO. l°-2S-6S I 12-5-6S ['. I ~~9 .... | 0ook Inlet ~d~-~5~[~ (390~l T~) to 5256~ ~ (~53~l ~) sU~V~AD~ Se~uga ~nas-Se56' ~{~538' r~) to 66~5~ ~ (567~': $~l-Induction-~%~ro~og 8, So~c~ Dens,ity, Sidewall. Neutron Porosit~i Continuous Di~eter ~' - ~ [" ~ C~G ~ (Re~ 'all strings set ~ ~11) ~ CA.LNG SIZE ~ 16" '! O-q /L " HOLE SIZE q 9-~/S', J ' 1 ' 111 ,11 , , ; D~-I~ ~V~ (~), $ ~o~'r ;~ ~ND OF ~AL U~ S~ATTAO~NT ~i~ FEB L "' ~6~. DIVISION O~ c.M; m,'-~ GAJ i i I ii i i i . I ii II I] II I I I [~. ~0~0~ , [ DATE FIRST PRODUC~ON [ ~'D~ION METHOD (~owh~g, g~ lift, p~p~--size and type of p~p) ~WE~ STA~S (~oduc~ or [ ~nut-in) Net produced ~Fet [ -Flow ~ . ] Shut-In ~ ~DUG~N '~STS-~ NOT ~N I ', F e" :1 : ,i' ~,..o.,.,o. o. ~.. (.o,..,., io; ~..,....,.,7.,~ ,' ,, I , I TEBT WITNESSED BY 'ShutZIn s~. ~lS~ o'-~f~ca~ , , , ': . I hereby c~tff-y~a~ the fore$ol~$ an~ttached information ts complete and ~rre%t as determined from all:available records *(S~e In~lrucfio.~ ._ INSTRUCTIONS General: This form is designed. for submitting a complete and correct well completion report end log on all types of lands and leases'i~i.~,,?laska. ._ ._ _~ Item: 16: Indicate which elevatiOn is used as reference (where not otherwise shown) for depth measure- ments given in other spaces on~ this form and in any attachments. Items' :20, and ]]:: If this well is completed for separate production from more than one interval zone (mul:liple completion), so state in item 20~ ~nd:' in item. 22 show the p~oJucing interval, or intervals, ~op(s), bottom(s) and name (s} (if any) for.P~[y'~he int~rvat reported in item 30. Submit, a separate.[e~rt (page) on this form, adequately identified,'[~rJ.~ach aaditional interval to ~ seperatel?" produc~, ~show: ing the a~itional data pertinent to suchCinterv~l. .. I~: "~cks Cement": AttaChed supplement~l records for this well should show the details of any mul- tiple stage cementing an~ the Iocation;~0fi t~e Cementing tool. Ite~ ]~: Submit a separate completion-~re~rt.on this form for each interval to ~ separately produ~. (~ instruction for items 20 ~n~:. 22 ~b?e)f~ ~'~ . w~ AN~ MUD IJ I I I I III . " .~ Coo~ Inlet ~.~ /j+t+5' 3904' ' ' : ~' Beiuga'"B" ~.o 6081' 5208' , ATTAC~g~NT, ~5 , ~;~ ., ';, ' '.'~. ¢~ ~Bol~ga': "C'i ~n~ 6598' 5658i ': .... .r,. -- I- " ,' . ~ ] , , , , , .~ .0 , , / DATA, A~ACII B~I~P D~C~IPI~ON~ OF LITI-IO~OQ~, K AND ~ETE(~FED S][OWS O~ OIL, . ... "-, ,_ , · Form RE¥1$ED , JAN. I , i)65 · STATE OF AI.ASKA . su-Mrr m ~uv~-zca-iz OIL AND GAS CONSERVATION CON~ITTEE GAS WELL OPEN FLOW POTENTIAL TEST REPORT, 4-POINT TEST Test Initial ~ Annual r-I · Special Field Producln~ Thru IBG. 8i~ I Wt/~t. IResergoir ~l I Test Date . ""-- 'SL~ o ~,._)~ '" ' A-~ · Temperature I Temper~tu~ I * · . . ~ ~ ~,~0' {Separator) I ~ngtb (L) -- Ratio MCF per Bbl. Llquia (Apl) JT~rpe Taps Type production from each zone Pipell~le' Cpnnection '%<, '-'-:" I'(.::.~xm', ... .Multiple Completion (Dual or Triple) OBSERVED DATA' Flow Data ' Time (Preve~ ~ Press, Diff, .Tubing Casing Flowing ,~o, of Flow (Line) (Orifice) h Press, . ' Press, Temp, Hours Size Size psig w pslg pslff *F ,. , t -¢.""" ' Z' 7i o '~o~." ',,~,,~,:.,,~ }~s'- ~.' ' .'~', , ~,~z6~ ,, ,, . 3- ,,, /'- ..' · '. ' ~:.~:- I ~ -' ' FLOXV CALCULATIONS Coeffi ..... Flow Temp. Gravity Compress. ~O. cient ---~/h p Pressure' Factor ~ Factor Factor Rate of Flow (24 Hr.)Vw m psia Ft Fg Fpv Q MCF/D , , :.... ~ ~7~ ~57~,W' ,-~, ~ m ~ ;~'~ ?.2, . . PRESSURE CALCULATIONS ., Absolute'Potential n ~ ~ ' L....% '.. ) )XCF/D · ~ : i i iii ii i, i i i i ii ii ]11 ii i ii i i ii i i i ,, i ~'-)/~ /, /?~ ,_~.~ (comply), ~d ~at X'am au~or~ ~y s~d comply ~ m~e ~ ~ ~d ~at ~ report was pre- tiliiViD pared ~der my s~i°n "d ~cfl. "d ~a, ~e fa~ s?~ ~ = ~.. co~,ct .d comple. W ~e ~ of ~ ~oWl~e.. DIVISION' OF OIL AND GAS ANCHOP~,GE lO 9 2 ~ 8 0~ ~ 3 2 3 4 1~!~ ~ ~i969 · DIVISION OF O~L AND GA~ ANCI~!Ot~GF,. 6 6 7 8 910 2 3 ,¢. · 5 6 7 8 910~) 2 3 4 5 6 7 8 910 SYMBOL OF SERVICE of SUB-SURFACE DIRECTIONAL, SURVEY o. , ~ECE~VE~) ' , MAR 19 'i9~° .., DIVISION OF OIL AN~ O,'~, .. · PHILLIPS PE TROLE UM CO. COMPANY A-2 PLATFORM A WELL NAME NORTH COOK INLET LOCATION · o JOB NUMBER II I _ [ _ IL - · AM-IlggG8 TYPE OF SURVEY SINGLE SHOT DATE ....... NOV. - DE C. 1968 · · ,,· · Ill'HQ IV' E~IICO IN U. LA. SURVEY BY ANCHORAGE, ALASKA . . OFT. ICE ,,.; ...... - ., :;;.~ ..,.~,~;,..,:.,. W-iE .L L C 0 M P L E.,~ ,,[,_~ N,.:. ~ E P O R T PAGE :;<~ .... ='>:~.' .. PHILLIPSm PETROLEUM-COMPANY WELL ~_2 -PREPARED FOR EASTMAN BY SCS TANGENTIAL MET~D6 tEASURED COURSE - - 0 E V I A T I 0 N .... C 0 U R S E T 0 T I L DEPTH LENGTH ANGLE DIRECTION ~MOUNT V.DEPTH LATITUDE DEPARTURE V.DEPTH LATITUDE DEPARTURE }RIGIN LOGATEU AT ND = 703. 125, 762. 62. 792. 30. -819. ... 27. 883. 64. ....... 979 . . .... 96 o 575.00, TVD = I I5° N 3 W 2 I5' N 66 E 4 O* N 70 E. 6 I5" N 67 E 7 L5° N 67 E 9 0° N 69 E 5?4.98, LATITUDE = 2.72 124.97 2.43 61.95 2.09 29.92 2.93 26.83 8.07 63.48 I5.01 94.81 2.72 N 0.99 N 0.71 N 1.14 N 3.15 N 5.38 N 1074. 95. 12 O' N 68 E 16.75 92.92 .... 1264. -.190. 18 45, N 65 E .. 61.07 179.91 1.356. 92. 20 15' N 66 E 31.84 86.31 1448 ........... 92. - .21 O' ..... N 67 E ...... 32.96 85.88 154I. ..1604. 1698. ..-1791. 1885. 1979. 2041. 2113. 2239. 2402. 252?. .... 2651. 2760. 2908. 2961. ~ 302Z. 3116. 3240. 336~.. 352Z. 3614. 93. 23 30' N 67 E 37.08 85.28 63. 24 45' N 69 E ..... 26.37 57.21 94. 26 45' N 69 E 42.30 83.94 93. 28 45' N 69 E 44.73 81.53 94. 31 I5' N 7I E 48.76 80.36 94. 33 45' N 72 E' .- 52.22 78.15 ~2. 35 15' N 72 E 72. 35 45' N 7I E ,I2~ 36 30' N 73 E lb3. 35 45' N 74 E IZS. 35 45' N 74 E 124. 36 O' N 75 E 109. 34 15' N 74 E i48. 30 O' N 71 E '53. 29 O' N 72 E 6t. 29 O' N 72 E 94. 30. O' N 72 E 124. 31 O' N 73 E 126. 32 4b' N 73 E 156. 34 45' N 74 E 92. 35 30' N 7~ E 35.78 50.63 42.06 58.43 74.94 101.28 .95.23 132.28 73.03 101.44 72.88 100.31 61.34 90.09 ' 73.99 128.17 25.69 46.35 29.57 53.35 46.99 81.40 63.86 106.28 68.16 105.97 88.91 128.17 53.42 7~.82 7.39 N 25.81N 12.95 N 12.88 N 14.48 N ..... 9.45 N 15.16 N 16.03 N 15.87 N 16.13 N 11.05 N 13.69 N 21,91 N 26.24 N 20.13 N 18.86 N 16.90 N 24.09 N 7.94 N 9.13 N 14.52 N 18.67 N ig.g2 N 24.50 N 13.82 N 5.45, DEPARTURE = 1.13 0.14 W 699.95 8.17 N 2.22 E 761.90 9.16 N 1.96 E 791.82 9.87 N 2.70 E 818.66 11.02 N 7.43 E 882.15 14.18 N 14.02 E 276.27 Ig.56 N 18.31E 1062.82 26.26 N 55.35 E 1249.81 52.77 N 29.08 E 1336.12 65.72 N 30.34 E 1422.01 78.60 N 34.13 E 1507.30 93.09 N 24.62 E 1564.51 102.55 N 39~49 E 1648.45 117.71N .41.76 E 1729.99 133.74 N 46.10 E 1810.35 149.61N 49.66 E 1888.51 165.75 N 34.03 E 1939.14 176.81N 39.77 E 1997.57 190.51N 71.67 E 2098.86 212.42 N 91.54 E 2231.15 238.67 N 70.20 E 2332.52 258.80 N 70.40 E 2432.91 277.66 N 58.96 E 2523.01 294.57 N '69.96 E 2651.18 318.66 N 24.43 E 2697.54 326.60 N 28.12 E 2750.89 335.74 N 44.69 E 2832.29 61.07 E 2938.58 65.18 E 3044.55 85.47 E 3172.73 51.60 E 3247.63 0.98 _ 3.21 : 5.17 : 7.88 : 15.31 : 29.33 47.65 E 103.00 r' ) 132.09 ~ , 162.44 E 196.57 E 221.20-E ~. 260.70 E 302.46 E 348.56 E 398.23 E .... 432.26 E : 472.04 E,~ .. 543.71 E 635.25 E 705.46 E 775.86 E 834.83 E 904.80 E 929.23 257.36 E 350.27 N 1002.06 E 368.94 N 1063.13 E 388.87 N 1128.32 E 413.38 N 1213.79 E 427.20 N 1265.40 E W E,,L ~L C O M, P L E.T I 0 N~ P,, F_P · . P~LLLIFS:: PET~OLEUM:-~_CDMP~NY WELL A-2 PREP~"E:~ 'FO. ............... E~'STMAN BY SCS ML~SUREO -COURSE - - D E V I A T I 0 N - C O U R S E DEPiH _LENGTH ~OLE DI~ECTIUN ~MOUN F V.DEPTH LATITUDE DEParTURE V.DEPTH . TANGENTIAL METROD . . .. T 0 T A L ,-~ LATITUDE DEPARTURE 3676. 3774. .3929. 4146. 4240. ~442 b. 4612. 4678. ~797. 4996. 5075. 5173. ~532 3. : 5517. .i 5735. ~-5826. · 6013. 627~. ....... b388 . ~.'.,b_aP-9 · 6824. 7010, .7319, 7626. 7834. 8145. -~8420. 62. 36 O' N 74'E 36.44 50.15 98. 36 30' N, 75 E 58.29 78.77 155. 31 Lb' N .75'E 93.82 123.38 217. 38 15' N 77 E 134.34 170.41 94. 38 45' N 77 E 58.83 73.30 186. 38 30', N 78 E 115.78 145.56 186. 39 O' N 79 E -~ 117.05. I44.54 66. 39 O' N 80 E 41.53 51.29 10.04 N 35.03 E L5.08 N 56.30 E 24.28 N 90.62 E 30.22 N 130.90 E. 13.23 N 57.32 E 24.07 ~ 113.25 E 22.33 N 114.90 E 7.21N 40.g0 E 3297,79 437.25 N 1300.43 E 3376.57 452.34 N 1356.73 EX 3499.95 476.62 N 1447.36 E 3670.36 506,84 N 1578.26 E 3743.67 520.07 N 1635.59 E 3889.24 544.15 N i748.84 E ~ 4033.78 '566.48 N 1863.75 E 40'85.08 573.70 N 1904.65 E 119. 39.30, N 79 E .......... 75.69 91.82 14.44 N .74.30.E_ 4176.90 588.14 N 1978.95 199. 39 O' N 79 E 125.23 154.65 23.89 N 122.93 E 4331.55 622.03 N 2101.89 ........ 79,-38..15' .....N.79..E ........... :...... 48'90 .... 62,04 ............ 9,33.N ....... 48.00 E 4393,59 621,37 N 2149,90..E ..... 98. 37 O' N 80 E 58.97 78.26 10.24 ,N 58.08 E 4471.86 631.61 N 2207.98 E . 150, : 35 0" ..N: 79. E ......... 86,03 122;87 194, 34 45' N 80 E 110.57 159.39 218. 35 45, ......N 81 E 127.36 176.92 91. 35 45' N 8i E 53.I6 73.85 18'7. 35 O' N .8i'E ...... 107.25 153.18 '2~2, 33' O' N 8[ E 142.69 219.73 116.41 N ,. 84.45 E , 4594.73 19,20 N 108.89 E 4754.13 19.92 N" 125.79 E 4931.05 8.31 N 52.5I E 5004.91 16.77 N . 105.93 E . 5158.09 22.32 N 140.93 E 5377.82 II3.' 3.1 O' .... N 8i.E ....... 58.19 96.85 9.10 N 217. 30 30' N 82 E lIO.I3 i86.97 15.32 N ,219. 31 15' N 8_2_E 113.61 187.22 15.81 N 1~6. 31 45' N'84 E 97.87 158.16 10.23. N 309 31 30' N 86: E. 161.45 263.46 11,26 N 307. 3._30}_._0.' N 89 E 155.81 264.52 2.71 N 268. 3o 15' ..]~'"-~'O--E , 104.78 179.67 0.00 N 311. 31 15' S 89 E 16i.33 265.87 2.81 S 275. 30. O' S 89 E 137.49 238.15 2.39 S 57.48 E 5474.68 109.06 E 5661.65 112.50 E 5848.88 97.33 E 6007.04 161.05 E 6270.51 i55.79 E 6535.03 648.02 N 2292.43 E~ 667.23 N 2401.33 E 687.15 N 2527.13 : 695,47 N 2579.64 712,25 N 2685,58 734,57 N 2826.52 743.67 N 2884.00 759.00 N 2993.07 774.81 N 3105.57 785.04 N 3202.gi 796.31 N 3363.97 799.03 N 3519.76 L04,78 E ~7-14,71 . 799,03 N 3624.55 161.31 E 6980.59 137.47 E _7218.74 796.21 N 3785.86 793.81 N 3923.34 E-~ ,LOSURE 4002'.84 N 78- 34' E I , ! ;iii · .'~ ! " J ! ' --. .1 ,.., ~ ' I I · · . o ! 1 ! I · ! ! '' i . 2&O0 ' -253 5 ' 25~5'-2660' 2660'-3d60' 3~60'-3600' .;3600'-38~5 ' 38~5'-3850' 3850'-39~5' 39~5'-3950' 3950t-&125' &125'-4375' 4375'-4420' ~20'-4~25' /~25'-&A~O' ~0'-~525' 4525'-&530' ~530'-~535' 4535'-~58~' &584'-&610' 4610 '-t~678 ' Phillips Petroleum Company N.C.I. Unit #A-2 North Cook Inlet Field Cook Inlet, Alaska SAMPLE DESCRIPTION Cong: gy, sdy,. unconsolidated, poorly srtd, qtz and igneous rock pebb.; w/occas, coal and clyst stringers Sand: gy, vcg, pebbly, poorly srtd, ang, predom, qtz. and igneous rock frag. Sand: dk gy, m-cg, poorly srtd, ang-subang, pred. qtz and igneous rock frag. Clyst: ~ and bm, slty, carb., soft, w/interbedded coal and sand, as above Sand: med gy, mg, med. srtd, ang-subang, predom, qtz w/abnt multi-colored grains Coal: blk, hd Sand: same as above Coal: blk, hd Clyst: it gy, slty, soft, w/interbedded coal and sand Sand: med gy, m-cg, slty, clayey, poorly srtd Clyst: it gy, slty, soft Coal: blk, hd Clyst: it gy, slty, soft Sand: med gy, f-cg, slty, poorly srtd Coal: blk, hd Sh: bm, slty, sdy, carb, hd Sand: it gy, m-cg, slty, clayey, poorly srtd, w/sctd pebbles and coal lam No sample returns Ss: It gy, m-cg, sli slty, friable, ang-subang, predom, qtz w/abnt colored ~ratns i ':2 ~?' ~ "7:~'i' ~'~ -2- Sample DescriptiOn, N.C.I.Unit #A-2 (Cont.) L678'-4690' 4690'-4700' L700'-4710' 1710'-4740' 4740'-4755' 4755'-t910' 4910'-4980' i980'-5040' 5040'-5160' 5160'-5200' 5200'-5230' 5250'-5320' 5320'-5400' 5400'-5600' 5600'-5630 ' 5630'-5645' 5645 '-6770' 6770'-6940' 6940'-7450' 74 50 '-7620 ' 7620'-8429' Sh: gy, micaceous, carb, soft to med. hd No samples Coal: blk, hd No sample returns Sh: gy, v. soft, tr. carb. mat. Ss: gy, mE, subang-suhrnd, fair srtd, abnt green, red, brown and nY Erains Sh: gy, slty, carb. Ss: as above w/interbedded gy, sdy sltst No sample returns Ss: gy, f-mE, subang-subrnd, v. fri to ~ncons, slty Sh: dk gy, w/thin coal streaks Ss: gy, f-mE, ang-subang, poorly srtd, w/ stringers of coal and carb brn sh No sample returns · Very poor sample returns - ss, coal, and sh, as above Ss: gy, fg, ang-subang, poorly srtd, friable, w/thin coal and sh stringers Coal: blk, hd Interbedded ss, clyst, sltst, and sh, ss - gy, f-mg, friable, poorly srtd, w/sctd coal fraE. No sample returns Interbedded clyst and sltst w/same ss and coal. Clyst - gy to bm, sft, carb. sltst- bm, firm, calc, carb. No sample returns Interbedded sltst and clyst w/some ss and coal. Sltst - gy, clayey, v. calc. Clyst- tan, firm, bent. Ss- gy, f-mg, friable, calc ~'~:i~ ~C ~i~ '-' Clyde R. Seewald ~ ~ ~ January 21, 1969 ATTAC~NT #1 28. PERFORATIONS OPEN TO PRODUCTION 44~5 '-M~88 d495'-4535'v 455&'-4630 4656'-4670 4800' -4821 4886 ' -4904 5047'-5059 5120' -51~2 5238' -5250 5504'-5510 5522 ' -5527 5628'-5632 5676'-5680 5702 ' -5708 ~-~5715 ' -5730 5798'-5808'~ 5879'-5888 5940'-5945 6002 ' -6011 6176 ' -6202 6260 ' -6286 6410 ' -6~+28 6600 ' -6610 INTERVAL, SIZE AND NUMBER) 7/16" 4 per foot II II I! II 1t I1 II 11 II II 11 II tl I1 I1 II II II II 11 II It II 11 11 ti I1 II 11 II II tl !I !I I1 II I1 II II I1 II !I II I1 tl 11 II II II II II 11 11 II II II II 11 It II I! II 11 II II 11 I1 I! II II II II II II II II 11 1! 11 II 11 II I1 II II II II FEBz "i ', DIVISION OE OiL A;,,iD GAS ATTACi~ENT ~%2 # . P.U ~LL.TPS P~:TROLT~U!.: h~.C.Y.Unit Tyonek Platfor~~ J'~c-. ~:1 - Cut 39' recovered 25' Cook ~nlet Sands. _ I ss, m-~-y, f-m ~r., sli slty, poorly sorted an~-sub~ng, fri~bRe, go~ p?:p, pred. qtz~abd, muir, i-colored grains, ~as odor, no ~uor. ss, aa,' except f. g.'.-& ~od. sort. 4Y~49 - 51 4451- 57 sh, m. g~/-blk, inter-l~inated, slty, mod. hard. ss, m~ gry, m-cosr~e-~rain, loose to firm, sli slty, poorly .~o~, ang-subang~, good p~..p, pred. qtz~mbd.~ ~uiti-colored g o~in.~, · r~ g,~,~ odor, no fluor., scat. shale lens~.s and plant frag. ~57 - 62 A~62- 64 ss, tt.'gry, f-gr, sli slty, mod. sort., friable, an.~-s~ang., good per. & pe~., pred. qtz~and ~bd. multi-colored Era!ns. · AA6&- 71 4~71- 73 ss, aa~ e~cept f-m gr. ss, aa, excep~ f~m ~'. w/thin irre!~lar blk carb. chalm ~,~_O~S. .4473- 75 A475 - ~A .~s, m. gry, n-c gr., sli slty, poorly sort., ang-suban~., £~ood p&p, pred. qtz~w/abd, multi-colored grains, gas odor, no fluor. .. ~ ~o recoverY. Cored .$9' - RecoVered 25'. . · Coring. t~.me r.~nged fro~ 1 minute to a foot to 12 minutes to the foot. :~ ~.,~,.~'., to ASgS" - preparing to t~.e Core ~2. -~.~ · . : . · Described by Clyde Seewald '" -'- " {. .~.C.I.Unit Tyonok Platform //A-2 .... ) ,-,-:-,- .".:, , ~.o,', ~,.~. ~u~ 56' re:':ow'mcd 5~' ' .',5.3a. 5 - 33 coal, blk haw, l sh' bm, ,~ity, sdy, carb., hard 533 - "5 ~.535 - sm, l.t. ~y, £-m gr, .l~y~ clayey, poor sort, fri, fair p~-p w/sh len$~m and b]J~ carb sh lamtn,,tions~ faint ~an odor s.~,. lt. gry, f-m ~r, slty, clayey, mod sort, good p~;p, fri, .fain~ .~as odor 4547- 5O 4550- 52 4552- 53 4555 A566 ~56~- 7'i A.7,- 77 L. 579- ~2 !,5s2 - 83 ~.5a3 - S sa, a= above, except coarse and' loss clay ss, lt. g.~/, =-c ?r, :~!'ty, clejey, poor sort, very good pf~p, an.g-suban~, gas ~'ior ss~ ~t. gry, :%= ~ ~!~, clayey, poor ~ort, f~_, good ~rosity an4 f~ir permeability, mag to sub~, some ve~ thin bl~ck coal l~n~tlons, g~ ss, it b~, m-c .~,' ~lty, cI~yey, poor sorted, a.n~, ~ood p~-p, ffas odor ~=~ it. g~, f-m .gm, s..gh,.!y clayey, mod-f~r-good ang-cuhc~*, x-bedd~, gsa odor . - S% as. above, w/abd white cl~v, clayey ~d co~ i~ulmftions ~, =..~me ,~ 4fi62-65 . ss, s=ma a= '4562-65 w/~bd w.bito clay clast= in aatrix and scat· tan b~ntonite, clayey ~bb!es a~ cobbles ~. m .:~., scat. p~b, ~l.y, clayey, ~ood ~p, anf;-sffoang, ~orly sorted, ga~ ~ior lt'. ~e, m-gr, scat. pcb, slty, abd white clay' clasts in :,~trix, fri, good porosity and ~a~_~ pe~'.~e&bili~y, ~ng-zubang, poor sort, gas odor.' · ss, as a~ve, exccpt 'fine gr sS, s.~ae ~.m A~71-77 except ~ine gr .w/carb. plant .~ra~ . ~,% '~m, u~ A571-7?.~xce~, x-bed- $.~ o,,~.o a~ A571-77 w/car.b. ~od 'grsg. Described by C!y~e Se~,,ald ~;. C. I. Unit Platfcr~ ?yonek ./~A-2 4678- 4.700, Cut 22', recovered 13~,. A.68!-~3 sh, gry-dk gry, sli "slty, vet"! soft sh, .¢ry-dk gry, sli city · , sh, am above, carb lmminations sh, as above, ned hard sh, gry, very slty, very soft · sh, gry, abd. plant fos.~ilo, carbonized, hard A670-91.5 sh, gry, slty clay, soft . · sh~ very Slty, very soft w/thin carb laminations 4~04 - 4806 - 4a12 4797 - &RlT, ,cut 2o,, recovered 19' ss, Kry, m ~.,?, suban.~-subrd, fair so~, abd ..~.~z~y, green, ~radns ~:/abd coal inclusions, s!i arm, good p,..%p, very faint gas odor, fri to ~nconsolidated above, f-m gr, trace amber gr.s ss, Fry, f gr, trace n .Fr, multicolored .~.rs as above w/white ely clas'ks abd, Food p~tp, £ri to unconsolidated ss, ,~ry', f-m gr, trace c-gr, sub~ug-.~ug, Door so~-b, abd multi-colored gr, coal inclusions, trace cly clasts, good porosity, fair permeability, fri to un¢o~usolidated ss, as above~ m-gr 4815 - 4.~I7 ss, Mr:r., f-m~gr, %r~.ce c-~r, some pebble, Poor sort, abd ~ulti~co!ored qra~ns, sli arg, trace coal inclusions, .good p&p,-very fri - sh, gry, hard, fairly mica, slty Described b~-A. O. ~owle · November 25, 1968 · '.1 C..,Un_.t PL~tfoz~ Tyonek ;?A-2 4996 - 5016, Cut 2.0' 3' sand, 17' sltst , recovered 20'. 4°96- 97 ~g97- 99 '49-P9- 5009 5,~9- I0 5010- 13 5013 - 16 ss, 73~/, f gr' subang-subrd, fair sort, fri, s!i arg, abd Varicolored gr.%ins, sca~. thin c~rb ianinations, good ~p ss, as above, v .,...,.~e.-.,a. ne gr., v ~lt¥ sit, fry,-sli sdy, soft to firm .~/thin carb /~Am~inations Slt~ as.~bove, except very shly sit, ~T~Y, soft to firm, fri, mica slt, as above, w/th£~ sdy lenses Described by A. G. Howle. ~,~ov~ber 26, 1968 PHILLIPS P!~T)OL.-'.~ CO:-.~ANY }~.C.I.Unit Platform ~'~yonck #A-2 5173-5199, Cut 26', recovered 26.. 5173 5180- 84 5184 - 85 51~5 - 87 ss, gry, ~-v f gr, subang-sUbrd, fair sort, fri, ,~lty, abd m~lticolored ~rns, abd cly ~la~s, so~t coal gms, ss~ 'as above, v ss, as above, £ ~r 5187 - 89 5189 - 90 5190 - 91 5191 - 92 5192- 97 5197 - 98 5198 - 99 ss, as above, - sltst, gry, ve~y .*dy, abd thin ~rb l~minations sh, gry, w f-gr, sd lenses. sh, dM gry, vez~y carb, frim -. Apparen~ .dip of bedding is. 8°. Dril!inK at 5390'. Described.by A. G. Howle November 27, 1968 ...... ::' ~'~,, - 6275-6292.5, Cut 17.5', recovered 16'5'. 6275 - vS.5 , . f.l ¢,.,. s m3. ea ~ cly~t, reed c~k ~, bent, small -' -~, of powddry ~en dry, .,.,a!y, irt bed.:iinr, easily cru~pled, ~ss carbonized marl stks 627~.5 - ao --' .~h firr'% irre. ~ in.g, clay,..~, reed dk ~.j, aly, bedd .~owd cry when 6~80 - ~:3.5 ..tKs, OCnSS ctayst, flY, shaly w/lt brn silts~. ~' £-m grains of .~J and' t~n qt~, .firm, drreg bed. non-ea!c .6283.5 - 86.5 63..%. 5 - 87. ~ 6387.5 - $9.5 - 6~..9.5 91.5, 6391.5 - 92.5 ~.,:, v-f-g, silty, subanr-$uord, dominant ~..~," qtz, ocass muscovite & brn mica flecks, w/carb stks, fi~, silts, stks, ...... ~ to bna, c.~rb, w/distinct beddLngplanos.. 35° e.o borahole ~.i '-ss, gy, f-g, dominant gy qtz, suban?subrd, -'. fri, easily cm:mpled, ocass carb matl, clayey ~. c!ayst, gy, w/li.~ht ~ CZ< bandinf:, w/abd carb m?.tl par~in~s, irreg bedding '~-.- ss, gy, r-.C, dom qtz, subang-subrd, c arb matl, fri, poss good ,,o recovery Samn!e at botto~ of core barrel included some coal nieces to 1". n s i- -~ ?orr'est E. Nelson .. e.. cfi ,-,, by ,~ov~nber 29~ 1968 , . . N.C.I.Unit Platform Tyonek ~?A-2 ~,?,?v? ,~ _ Cut &9', re~Jvered 49', 638,8 6437 9,, 639& - 6AO1 64~'~ 05 64.05- 1.3 61,13 - 19 6419 - 21- 61,21 6428 6&31 - 33 6433 - 34 6434- 37 c!yst, r,~-dk ..~ry, bent, sli .~Ity, w/cart and thin coal !..%minations, irt beddln0q c!yst, as above, ::'/numerous coal 2" beds, very cart clyst, m-hd K, plant frae, 2" coal !.s~.~.in:~tions s.~, ~r..ry, m-Kr, subanR-subrd, qtz, so~ue ?teen mineral, t.r coal pieces & chips, good p&p, ver~y fri, gas ·odor ss~ as above, no coal or cart, very friable ~ clyst, m-,~.ou~/, bent, n~erous cart .- hard:, mica ~ ss~ m-dk. ~,, f-~, subrd, bent w/cart · :' -' abd c!y~ poor sort~ d~ - ~-,.~, soft, poor . ' ~ "' 3 mudst, ~-g~, w/cash mat, soft, irrog . ' "' bedding s!t, gry, ccc clay clast, mica, t~-orange colored pl.~ut frag, hard ss, ge;, f-gr qtz, sub~ung-subrd, fri, sol%, fair - -'~ coal, blk, hardr solid, dip 38° ~ ciyst, ~r, bent, slty, dirty, tan-orange · clay cla~ts Apparent formation dip 7° Described by ~orrest E, Nelson December 2~ 1968 ATTACHMENT CHRONOIDGICAL WELL HISTORY Spudded from surface. Drilled 15" hole to 630', reamed to 22" to 504', twisted off. Recovered fish, reamed hole to 22" to 630' and set 16" casing at 620.76' cemented w/825 sacks WOC. , · Drilled 15" hole to 2360', pipe stuck, spotted oil, pipe came loose, drilled 15" hole to 2658' set 10-3/4" casing at 2636.66' cemented w/14OO sacks. 1/17-30/68 Drilled 9-5/8" hole to 6342'. (Cored 4445'-4484' 4528'-4584' 4678'-4700' 4797'-4817' 4996'-5016' 5173'-5199', 62?5'-6292' 6388'-6437') Drilled 9-5/8" hole to 8429'. (Cored 6388' -6437'). Set cement plug (8429' - 7258' ) 84 sx Class G cement w/2% CaC12. Set 7" casing @ 7189.36' RKB, cemented 1st Stage w/428 sx Class G cement, cemented 2nd Stage w/620 sx Class G cement. Top of cement 5196'. Drilling out cement. PBTD 71~'. Perf· 6602' - 6612' and 6412' - 6430' Test Interval #1 thru 40/64" choke, FARO 1045 MCFD, FTP !90$ PSI. Test on 46/64" choke, FARO 3700 MCFD, FTP 15lO PSI. Perf· 6]40' - 6148', 6176' - 6203', 6260' - 6286'. Test Interval #2 °n 3/8" choke, FARO 6450 MCFD, FTP 1935 PSI. Test on 1/8" choke, FARO 750 MCFD, FTP 21OO PSI. Left Baker Recorder in hole. Perf. 5504' - 5510', 5522' - 5527' 5628' - 5632' 5676' - 5680' 5702' - 5708', 5715' - 5730', 5798' - 5808', 5879' - 5888', 5940' - 5945' 6002' - 6011' Test Interval #3 on 3/8" choke, , · FARO 5945 MCFD, FTP 1865 PSI. On 5/8" choke, FARO 8567 MCFD, FTP ]400 PSI. Perf. 504?' - 5059', 5120' - 5142', 5238' - 5250'. Test Interval #4 on 3/8" choke, FARO 6758 MCFD, FTP 1865 PSI. Perf. 4886' - 4904', 4800' - 4821'. Test Interval #5 on 3/8" choke, FARO 5189 MCFD, FTP !6OO PSI. Perf. 46?0' - 4656' 4630' - 4554', 4535' - 4495', 4488' - 4445' , · Te~t Interva3_~6 on 3/8" choke, FARO 54?5 MCFD, FTP 1500 PSI. On 1/8" choke ~F~RO 581.MCFD, FTP 1562 PSI. On 3/16" choke, FARO 1334 MCFD, FT~ 1540 PSI. On ½" choke, FARO 8350 MCFD, FTP 1240 PSI. On3/4,' choke, FARO 16,950 MCFD, FTP 1085 PSI. Cleaned up Lower Zone 5404' to 6610' on 3/4" choke. FARO 28,300 MCFD, FTP 1950 PSI. Cleaned up ~ddle Zone~4800' to 5250' on 3/4" choke, FARO 26,300 MCFD, FTP 1800 PSI. Cleaned up Upper Zone 4445' to 46?0', FARO 22,350 MCFD, FTP 1540 PSI. Ran 4 point back pressure test on Upper Zone. Test #! - 3/4" choke, 2-3/4 hours, FARO 20,410 MCFD, FTP 1303 PSIG. Test #2 - ½" choke, 2¼ hours, !.i~ ~ ~ .~.~i .5 ATTAC~{EN~~# -2- FARO 9950 MCFD, FTP I~67 PSIG. Test#5- 5/8" choke, 2½ hours FARO 5500 MCFD, 1~95 PSIG. Test #~ - ¼" choke, 1½ hours, FARO 2580 MCFD, FTP t~92 PSIG. Ran ~ point back pressure test on Lower Zone. Test #1 -'5/~" choke, 1½ hours, FARO 25,550 MCFD, FTP 1557 PSI. Test #2 - ½" choke, 1~ hours, FARO 15,O75 MCFD, FTP 19&5 PSI. Test #5 - 5/8" choke, 1½ hours, FARO 7~O0 MCFD, FTP 2026 PSI. Test #~ - ¼" choke, 1½ hours, FARO 5260 MCFD, FTP 2065 PSI. Ran 2 point back pressure test on ~.~ddle Zone. Test #1 - 3/~" choke, 2½ hours, FARO 25,650 MCFD, FTP 1518 PSI. Test #2 - _~/8" choke, 1½ hours, FARO 17,875 MCFD, FTP 1667 PSI. Test #5- ½" choke, 1-5/& hours, FARO 12OO MCFD, FTP 1786 PSI. Test #& - 5/8" choke, 1-5/& hours, FARO 6755 MCFD, FTP 18&5 PSI. Phillips Petroleum~ Company N. C.I. Unit #A-2 North Cook Inlet Field Cook Inlet, Alaska 2400 '-253 5 ' 2535 '-2660' 2660'-3460' 3460'-3600' ~3600'-3845 ' 3845 '-3850 ' .3850 '--3945 ' 3945'-3950' 3950'-4125 ' 4125 '-4375 ' 43 75 '-'4420' 4420'-4425 ' ~25 '-4440' 4440 ' -4525 ' 4525 '-4530: 4530'-4535' 4535'-4584' 4584 '-4610' 4610'-4678 ' ~m -- m mm ~m -- m SAMPLE DESCRIPTION Cong: gy, sdy,. unconsolidated, poorly srtd, qtz and igneous rock pebb.; w/occas, coal and clyst stringers Sand: gy, vcg, pebbly, poorly srtd, ang, predom, qtz. and iKneous rock frag. Sand: dk gy, m-cg, poorly srtd, ang-subang, predo qtz and igneous rock frag. Clyst: gy and bm, slty, carb., soft, w/interbedded coal and sand, as above Sand:. med gy, mg, med. srtd, ang-subang, predom, qtz w/abnt multi-colored grains Coal: blk, hd Sand: same as above Coal: blk, hd Clyst: it gy, slty, soft, w/interbedded coal and sand Sand: med gy, m-cg, slty, clayey, poorly srtd Clyst: It gy, slty, soft Coal: blk, hd Olyst: It gy, slty, soft Sand: med gy~, f-cg, slty, poorly srtd ~.i ~.ii~~ / · Coal: blk, hd ~..... ~ · Sh: bm, slty, sdy, carb, hd Sand: it gy, m-cg, ~slty, clayey, poorly srtd, w/sctd pebbles and coal lam , No sample, returns · Ss: It gy, m-cg, sli slty, friable, ang-subang, predom, qtz w/abnt colored ~rains --2'- A678'-4690' - 4690'-4700' - 4700'-4710' - Sample Description, N.C.I.Unit #A-2 (Cont.) Sh: gy, micaceous, carb, soft to med. hd No samples Coal: blk, hd 4710 ' -4740 ' - 4740'-4755' - 4755 '-4910' - No s~mple returns Sh: gy, v. soft, tr. carb. mat. Ss: AY, mg, subang-suhrnd,.fair srtd, abnt green, red, brown and gy Erains &910'-4980' - Sh: gy, slty, carb. 4980'-5040' - Ss: as above w/interbedded gy, sdy sltst 5040'-5160' - No sample returns 5160'-5200' - 5200,45230, - 5230'-5320' - Ss: gy, f-mg, subang-subrnd, v. fri to uncons, slty Sh: dk gy, w/thin coal streaks Ss: gy, f-mg, ang-subang, poorly srtd, w/ stringers of coal and carb brn sh 5320'-5400' - No samPle returns 5400'-5600' - Very poor sample returns - ss, coal, and sh, a~ above 5600'-56~0' - 5630'-5645' Ss: gy, fg, ang-subang, poorly srtd, friable, w/thin coal and sh stringers Coal: blk, hd 5645 '-6770' Interbedded ss, clyst, sltst, and sh, ss- gy, f-rog, friable, poorly srtd, w/sctd coal~frago 6770~-69d0' - No sample returns 69d0'-7450' Interbedded clyst and sltst w/same ss and coal. Clyst - gy to bm, sft, carb. sltst- bm, firm, calc, carb. 7450'-7620' - No sample returns 7620'-8429 ' Iht erbedded slt st and clyst w/some ss and coal. Slt st - gy, clayeY, v. calco Clyst- tan, firm, bent. Ss- gy, f-m~, friable, calc Clyde R. Seewald January 21, 1969 ATTAC?~NT~ nW~}, ~ '"'T ^~' ..ISTORY Spudded from surface. Drilled 15" hole to 650', re-amed to 22" to 504', twisted off. Recovered fish· reamed hole to 22" to 630' and set 16" casing at 620 76' cemented w/825 sacks WOC · · · · 11/?-16/66 Drilled 15" hole to 2360', pipe stuck· spotted oil, pipe came loose, drilled 15" hole to 2658' set 10-3/4" casing at 2656.66' cemented w/1LOO sacks. 1 / 7-3o/68 Drilled 9-5/8" hole to 6342'. (Cored 4~+5'-~84', 4528'-4584', 4678'-47OO', 4797'-48!7', 4995'-5016', 5173'-5199', 6275'-6292', 6388'~6437'). Drilled 9-5/8".hoie to 8429'. (Cored 6388' - 6437'). Set cement plug ($429' - 7258') 84 sx Class G cement w/2% CaC!2. Set 7" casing © 7189.36' P~B, cemented 1st Stage w/~28 sx Class G cement, cemented 2nd Stage.w/620 sx Class G cement. Top of cement 5196'. .Drilling out cement. PBTD 71~'. Perf. 6602' - 6612' and 6412' - 6430'. Test Interval ~1 thru 40/64" 'choke, F~.RO 10~5 MCFD, FTP 1900 PSI. Test on 46/64" choke, FARO 3700 MCFD, FTP 15lO PSI. Perf. 6140' - 6148', 6176' - 6203', 6260' - 6286'. Test Interval ~2 on 3/8" choke, FARO 6450 MCFD, FTP 1935 PSI. Test on 1/8" choke, FARO 750 MCFD, .FTP 2100 PSI. Left Baker Recorder in hole. Perf. 550~' ' 55!0', 5522' - 5527', 5628' - 5632', 5676' - 5680', 5702' - 5708', 5715' - 5730', 5798' - 5808', 5879' - 5888', 5940' - 5945', 6002' -6011'. Test Interval #3 on 3/8" choke, FARO 59~5 MCFD, FTP 1865 PSI. On 5/8" choke, FARO 8567 MCFD, FTP 1400 PSI. Perf, 5047'-- 5059', 5120' - 51~2.', 5238' - 5250'. Test Interval #4 on 3/8" choke, FARO 675.8 MCFD, FTP 1865 PSI. Perf. ~886' - ~904', 4800' -4821'. Test ~Interval #5 on 3/8" choke, FARO 5189 MCFD, FTP 16OO PSI. Perf. 4670' - 4656', ~630' - Test Interval //6 on 3/8" choke, FARO 5475 MCFD, FTP 1500 PSI. On 1/? choke, FARO 521 MCFO, FTP 1562 PSI. On 3/16" choke, FARO 1334 MCFD, FTP 1540 PSIo On ½', choke, FARO 8350 MCFD, FTP 1240 PSI. On 3/4!' choke, FARO 16,950 MCFD, FTP 1085 PSI. Cleaned up Lower Zone 5404' to 6610' on 3/4" choke. FARO 28,300 MCFD, FTP 1950 PSI. Cleaned up Middle Zone .4800' to 5250' on 3/4" choke, FARO 26,300 MCFD· FTP 1800 PSI. Cleaned up Upper Zone 4445' to 46?0', FARO 22,350 MCFD, FTP 1540 PSI. Ran 4 point back pressure test on Upper Zone. Test -//1-,3/4" choke, 2-3/4 hours, FARO 20,410 MCFD, FTP 1303 PSIG. Test -//2 - ½" choke, 2¼ hours, : · · ATTACH?-~N~ ~ -2' #3 2-!~- hours FARO 9950 MCFD, FTP lg67 PSIG. Test - 3/8" choke, ~,~ i'~4 ¼" 1½ hours FARO FARO 5500 MCFD, L495 PSIG. Test - choke, , 2~ MCFD, FTP ~92 PSIG. ~n 4 poir~ back pressure test on ~' -'~/~" choke, 1~ hours, FARO 25,550 Lower Zone, Test i;1 F.~ 1557 PSI Test //2 - ~" choke, I~ hours,-FARO 13,O75 ~.~C~D, FTP 19~3 PSI. Test ~ - ~/8" choke, l~ hours, FARO 7~O0 ~[CFD, FTP 2026 PSI. 'Test ~g - ~" choke, l~ hours, FARO 3260 MCFD, FTP 2065 PSI. ~n g point back pressure test on ~.~ddle Zone. Test ~l- ~/~" choke, 2~ hours, F~O 25,650 MCFD, FTP 1518 PSI. Test ~2 - 5/8" choke, l~ hours, FARO 17,875 MCFD, FTP 1667 PSI. Test ~ -~" choke, 1-3/~ hours, F~O ~OO MCFD, FTP 1786 PSI. Test ~ - 3/8" choke, 1-5/g ho~s, FARO 6735 MCFD, FTP 1895 PSI. coal, blk ha~ 1~53~. 55 - .33 bm, ~lty, My, earb., hard 535 - 35 ss, 2.t. gry, f-m gr, slty~-clayey, poor sort, fri, fair p~.~ w/sh l~s~ and b~ c~rb sh !~fnations, faint ~as odor g535 - g? s~, It. gry, f-m _~n', slty, clayey, mod sort, au~-~ub~u~, good p&p, fri, fa~.nt ~as odor s~, as above, except coarse and leSS clay ms, lt. gry, z-c .~r, .~l~y, cl~yey~ poor sort, very good pf~p, 4552- 53 It. g.~,, f-m ,~.~, s!ty, clayey,, poor aort, fri, good. ~rosity ~nd f~ir ,~e~e.,oili~y, ang %o sub~, sone ve~ ~ b.!sck coal l~n~tio~s, gaa ~]or ~553 - 62 ss, 1%. &~y, m-c gr,' slty, clayey, poor zorted, ~ood p.~p, gas odor A562 - 65 It. gry, f-m ~, slightly clayey., mod-fair-good p~p, an~.~-zuhang., x-bedded., g~s odor /,565- 66 ss, as above,, w/a~x~, white clay, clayey and co~l fi-f66- 67 4567- 68 ~ ~ w/~bd wh~ te clay c!~sts in matrt w and c: ~ clay, y ~bb!es a~ cobbles scat. tan b~nt mi~e, . ss., It. ~wv..?.~., m-~, scat. ~b, zlty, clayey, rood of~p,.. mng-suban~, poorly sorted, 571 - 77 ss, lt'. ~y, m-~gr, scat. pcb, slty, abd white clay clasts in ~tri×, fri, (~ood ~sity and fair pe~:~eabillty, ang-~ubang, ~or so~, gas ~or · A577 - 7~ ss, a.,,s a~ve, except fine gr fi57.~- 79 ~s., s~mae as A57i-77 except fine gr w/carb, plant fi579 - 82 ASs2 - ~3 Described by Clyde Seewald D!VIS!ON OF ~_.i~. ,~ · 3 1;2 Unit Piat form Tyon ek .i~A_2 4678- 4700, Cut 22', recovered 13}'. 467~- 79 sh, gry-dk gry, sli slty, ve~7 soft ~6~0-81 sh, ..~y-dk gry,~ sli s!ty sh, am above, carb laminations A681-.~3 sh, as above, ned hard sh, gry, very slty, very soft A6~6-~9 sh, gry, abd. plant fossils, carbonized, hard sh, Ery, $1ty clay, so.ft L690-9!.5 very Slty, very soft w/thin earb laminations Described by ~. G. t{owle %~.C.I.Unit Platform Tyonek A797 - A817, .Cut 20', recovered 19' ss, gry, m ~r, subanf-subrd, fair sort, abd .~y, green, ~zra~ns w/abd coal inctusionm, sli arm, good ?~%p, very faint gas odor, fri to ~uconsolidated 4798- 99 above, f-m gr, trace mmber fr.s ,,t,.799- /..80~ 48O6 - 4~12 ss, ~ry, f gr, trace m Mr, multicolored ~rs as above w/white c!y clasts abd, Food ~?..p, fri to unconsolidated · ss, ~ry, f-m gr, tr~-~ce c-gr, sub~ug-ang, poor sort, abd multi-colored gr, coal inclusions, trace cly cl.~sts, good porosity, fair permeability, fri to unco~:.~olidated ss~ as above, m-gr ss, Kry, f-m~..~r, trace c-~r, some pebble, Poor sort, abd ~u!ti~co!ored .~ra~.ns, sli arg, trace coal inclusions, good p&pj very. &8!5 - 4~17 sh, gry, hard, fairly mica, slty Described b'~ A. G. Noveuber 25, 1968 !.!.C. ?, Uni~ PL~t£onn T.vonek .{:,'A-2 1~996 - 5016, Cut 20', r~.covered 20'. 3' Sand, 17' sltst &~9o - 97 A997- 99 499~- 5009 5~9- 10 501.0- 13 5013 - 16 ss, ~, f gr, subang-subrd, fair sort, fri, s!i abd varicolored grains, ~cat. thin carb laninatlon$, good r~p s~, as above, v fine-fine gr, v slty slt, .g~, sli sdy, soft to firm w/thin carb lamin~:tions . mlt, as above, except very shly slt, ~TrY, soft to firm, frt, mica slt, as above, w/thin sdy lense~ Described by A. O. Howls ~ovamber 26, 1968 5173-5199, Cut 26', recovered 26'. 5173 - 80 5180- 84 51S4 - 85 5185 - 87 5187 - 5189- 9O 51.90 - gl 5191 - 92 5192 - 97 51g7- 98 5!9~- 99 /c as, gry, f-v f gr, suban~-$ubrd, fair sort, fri, slty, abd multicolored turns, abd cly clasts, sc~t coal ~rns, good p~-p ss, as above, f-Er ss, as above, v f-gr ss, as above, f gr ss, as above, v f-~Tr sltst, gry, very sdy, abd thin carb la~.~naticns sltst, dR .~zry, v sdy, carb ss, dk Sty, m-~.~r, slt laminations, v ers carb gms, good p~.p, fri ss, dk gry, m-Mr, sm c-gr, ang to sub~n~, poor sortiug, fri, very slty, abd gry & green, s;~ very ers sh, gry, w f-gr.~ sd tensee sh, dk g.~r, ve~ carb, frim Apparen~ .dip of beddirq~ is 8©. Dril!in,.~ s.t 5390'. Described .by A. G. Howle ~cve~b~r 27, 1968 ...... - 6275-0292.5, Cut 17.5', recovered 16.5' · · . 6275 - ~. 5 civ-+. ,~.-~, meal dk ~, bent, ~mall ~lecIcs of powd6ry ~.&en dry, shaly, irt bedding, easily crumpled, poss carbonized marl stks 6278.5 - ~. cl~vst, reed dk .~r, vhaly, fir~% irro~ beddfn}~, ~oowdery when dry 6280 - 83.5 clayst, gy, shaly w/It brn s!.lts~ '~ f-m ~rains of ~ and t~ ~tz, .firm, ~.rre~ bed.', non-ealc .62~3.5 - 86.5 s~, ned gy, v-f-E, silty, suban~-subrd, dominant ~ qtz, ocass ~,:scovlte & brn mica flecks, ~//~arb stks, firm, silts, stks, reed to bra, carb, w/distinct bedding planes 35© to borehole 6386.5 - 87.5 ~s, gy, f-g, dominant FY qtz, subang-$ubrd, fri, easily m~pled, ocass carb matl, clay:.y, ,~, 63S7.5 - Sg. 5 6389.5 - 91.5 ~. c!ayst, gy, w/li.~ht & dJ~ banding, w/abd carb m~,~tl partln~s, lrreg bedding ss, ..:y, £-g, dom qtz, suban,z-subrd, c arb mat!, fri, po s s go od p&p. 6391.5 - 92.5 ~o .recovery Samole at bottom of core barrel included some coal nieces to 1". Described by ?off'est E. Nelson :~ov~nber ~9, 1968 ~.C.I.Unit Platfor~ Tyonek ,~A-2 Cut &9' recovered 49', 63~8 - 6437 63~- 9!, clyst, m-dk ,,~"y, bent, sli ~lty, w/czrb and ~hin coal !&minabJons, lrr beddln~ 639A - 6AO1 c!y~t, as above, w/numerous coal 2" beds, very carb 6&O! - 05 /? clyst, m-hd g. plant fra~, 2" coal l~'~inutions 6~05- 13 s~, ~ry, m-gr, sub~n.~-subrd, qtz, so.ua ~reen mlneral, tr coal pieces & chips, good p fri, gas 'odor 6A1.3 - 19 ~3 ss, as above, no coal or c~rb, vary friable 6&19- 21 clyst, m-iffy, bent, n~z~erous carb . ~raom, very hard, mica J~ ss, =-dk f~, f-gr, subrd, bent w/cart mat, abd ely, poor sort, dirty, soft, poor p&p 6!~25 - 28 3 mudst, brn-gry, w/cart mat, soft, irrog beddinE sl~, gry, otc clay clast, mica, t~-orange colored pl~ut frag, hard 6L31 - 33 ~ ss, g~y, f-gr qtz, sub~ng-subrd, fri, 6h.33 - 3~ coal, blk, hardr solid,dip 38° 6434- 37 clyst, g~r, bent, slty, dirty, t~n-orange clay ¢lasts Apparent formation dip 7© Described by Forrest E. Nelson ~;.. ~,-.,b~.~r 2, 1968 LOCATED IN THE APPENDIX UI WFL [21 IPR LOG CALIPER SURVEY [21 VOLAN UI CURVE DATA [21 STRATIGRAPHIC HIGH RESOLUTION DIPMETER [~ OTHER: Jaauary 7, 1969 ltor~h Cook Inlet Ho. A-2 Phillips Petroleu~ Co~p~, Opera,or Dear ~r. Dunbar: I have one question regardtn~ this report. U°tice 'Chat your Test Intervals No. & and Ho. 5 shov the identical produat~on rac~s ami pressures for tim choke s. ise. Is this Very truly yours, Larl L. Yon~~e ]inclosures Form N'o. P--4 ~zv. ~-~o-~ STATE OF ALASKA SUBMIT IN DUPLICAT~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT O'F :DRILLING AND WOR'KOVE.R OPERATIONS ~.API NUAIEI:LICAL CODE ~0-283-20018 6. LEASE DESIGNATION AXD SEI~IAL NO. L--lVS¢9 ?. IF INDIA)3', ALOTTEE OR TRIBE NAME OIL [--'1 GA8 ~ WELL WELL OTHER 2. NA/~E OF OPI~%ATOR Phillips Petroleum Company 3. ADDRESS OF OPEP, ATOR 515 "D" Street~ Anchorage, Alaska 4; LOCATION OF WELL 99501 UTqIT,FA.RM OR LEASE NAME North Cook Inlet Unit g. WELL NO. 10, FIFJ.,D AND POOL, OR WILDCAT Leg 3, Slot 5, North Cook Inlet Unit, Platform Tyonek, 1255.72' FNL, 1089.16' FWL, Sec. 6, TllN, Rgw, S.M. North Cook Inlet 11. SEC., T., R., M., (BOI~OM HOLE on, mCTn~ Sec. 6~ TllN~ R9W~ S.M. 12, PEI~MIT NO. 68-91 13. REPORT TOTAL DEPTH AT END oF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFO.~TIONS, TESTS AND RESULTS. FISHING JOB~, JU'NK IN HOLE AND SIDE-TR~CKED HOLE A/VD A_NY OTHER SIGNIFICANT ~,~ES IN HOL]~ CONDITIONS. 11/30 T.D. 6342'. DRILLING. ::]_o/28 Spudded from Surface. Drilled 15" hole to 630', reamed to 22" to 504', twisted off. Recovered fish, reamed hole to 22" to 630' and set 16" casing at 620.76', cemented w/625 sacks. WOC. Drilled 15" hole to 2360', pipe stuck, spotted oil, pipe came leose, drilled 15" hole to 2658', set lO 3/4" casing at 2636.66', cemented w/ 1400 sacks. 11/17-30 Drilled 9 5/8" hole to 63~2'. (Cored ~/J+5'-~J,84', 4528'-4584', 4678'-4700', 4797'-4817', 4996'-5016' 5173'-5199', 6275'-6292', 6388'-6437') RECEIVES DEC 6 196¢ DIVIIION OF OIL AND OA$ ANCHO4~AO~ $,GN]~D .~~ .~, :~ District Office ..~L~naMer ..,,,.,.~ 12-,5-68 ..OTE--Report on this form is ~equired for each calendar month, r e9ardless of the status of operations, anti must be filecl in duplicate ~ith the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. PHILLIPS PETROLEUM COMPANY ANCHORAGE, ALASKA 99501 ~ 515 "D' STREET EXPLORATION AND PRODUCTION DEPARTMENT / :'"/~ 1 lC..-" , Oc~;oYcr '5) ~ · . Re: Spud new well I'~::T,'I '"'~ - . ........ ~-2 Del:':: '~'"f ..... ',' [-. ......... ~rv~.]_ Resources Q J ? ;:.-J- 1-~ ;', w C~-~ ., ........ f'~] ,:.:,,:, .... ' ¢_ .....%..,(. ~ - ', · . . Dear Sir: :.~'.z i~s L,-, ', '.~ ,- ', * . -; r.~ v'ou that the subject 'well was sPudded on" ...... L"'"' ,'qT ~r~q~a ,?3Z ].3':00 hOUrS on October 28, 1968. The surface q,~na~"i.n'~ o'~ · ~,'~';~ weS! '~s a+. n~.'SA, ~,~L 3.O~-9' F¢.~, Sec 6, T-Il-N, ~,_o_,,. 3" . . . . -r~-, F.]_ar' ',"-.~ dr:ill 'this ;.;ell .directSonally to'a bottom h~-,o "',-. , ,'-' i,.c~2..,~' ~,'??T~ ..~,, ..,.,...~,O4~. q F:?L,., Sec. 6, T].].N, R9W, S.ICi. Very truly yours, · . . ~. ,q' ,~ [.,.rv PHILLIPS .P.,TROL,~'_ CO~Dh~ . RECEIVED NOV DIVI$1OH'oF OIL AND OAS ANCHOi~GE ,% DIRE CTOtfS OFFi J Date Noted -~ ...... j ~ // / Lands ~---,~-- -' '- , ~/ .: .' ...'~ / 1 Admin - .-~[ .... / _ '" ~ h~Oso,nment~ .~ ..,~__ Oetob~ L~, 1968 Re: Horrh Cook l, nler ~c A ~,2 .lPhillipo l)e~oleum Cempm~, Oper~ A~lm 99501 ~losed please find the app~ applJ, cf~tf.ou for l~r~Ltt chips ~ Ii;. Naz'shall, Jr. Petroleum Supervisor FORM SA-18 t 25.5M 8/67 MEMORANDUM State of Alaska DFFL~OH OF 013, AI~ GAS SUBJECT: FORM SA. lB 125.SM 8/67 MEMORANDUM State of Alaska DATE Form REV. 9-30-67 STATE OF ALASKA SUBMIT IN TRIPIi (Other instructions reverse side) OIL AND. GAS CONSERVA,TION ,COMMITTEE' APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLL~3 BACK JR. TYPE OF WORK DRILL [] DEEPEN I--J PLUG BACK [-J b. TYPE OF WELL WELL WELL OTHER ZONE ZONE 2. NAME OF OPERATOR Phillips Petroleum Company 3. ADDRESS O~ OPERATOR 515 "D" Street, Anchorage, Alaska~, 99501 4. LOCATION O~At surface WELL Leg #3, Slot #5, North Cook Inlet Unit, Platform "A" 1255.72' FNL, 1089.16' F%~[L, Sec. 6, TllN, R9W~ S.M. At proposed prod. zone ;,g2.51 FNL. 26;,.3 FF.T,. Sec. I~.'DIS~ANCE IN ~VlILES ~Nb DIRECT:ON F.~OM N~AREST TOWN bR~OST-OF~ICE* 10,~ liiles Eas% of Tyonek, ~qaska ~4. BOND INFO~ATION: ~-ML-IV Statewide Bond #Bi-1 6. LEASE DESIGNATION AND SERIAL NO, ADL-17589 · 1. IF INT)IAN, AiJ~)TTEE OR TRIBE NAME 8. UNIT~FAR1VI OR LEASE' NAME North Cook Inlet Unit 9. WELL NO. ~ #2 10, FIELD AND POOL, OR WILDCAT North Cook Inlet 11. SEC.-, T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 6, TllN, RgW, S.M. 12. TYPE Surety and/or No 15, DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit if any) ~4916' I~.-DISTANCE' FROM PROPOSED LOCATION* TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 5850' 16. NO. OF ACRES IN LEASE i~.' ' 5002 ~ PitoPOSED DEPTH 8150' MD 7000' TVD Axnou~t 17. NO. ACRES ASSIGNED TO THiS WELL 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START* November 13:]..968 21. ELEVATIONS (Show whether DF, RT. CH, etc.~ RKB !16 feet from M?:LW .. 23. PROPOSED .~ASING AND .~EMENTING PROGRA1VI QUANTITY OF CEMEN~ ,. SIZE OF HOLE SIZE OF CASING} WEIGHT PER FOOT GRADrE SETTING DEPTH ' ,,, 22" ] 6" A.~# T-T-L_~ AOD ~ ~ rCuq''a~e' to Surface 15" lO-3/&" LS. ~ &. 5~ J-55. ' 2.g~0~ d~m~qn.ta, to m~fana g-~/s,, 7,, '-26~.~ ~ 5-55 8:nqo, - ~i]] .~..+.~ qnn,. ~_h~,~ ~.= ~ : 1. Deviation required to reach BHL from permanent-platfOrm. 2. There are no affected operators. 3. BOP Specifications attached. Inte~als of interest will be perforated and~may be stimulated. e,'- Refer to State of Alaska, Alaska 0il & Gas Conservation Committee, Conservation Order #i0, dated 6-8-67. subsurface locations and measure4 and proposed ne~--productive zone. If proposal is %0 arlll or aee. pen alre,:m..onaiiy, ~rue verdi/depths. Give blowoat preventer program. 24. I hereby cdrtif~ that the Forcgoin~'ue and Correct ~~. ~~'~ DATE October 9, 1968 TI~ 0£fice Manager (This spac~o/r'~State office use);2F' CONDITIONS OF APPROVAL, IF ANY: SIGNL-'D SAMPLES AND CORE CHIPS REQUIRED [ OTHER REQUIREMENTS: [] eES Z' ~0 A.P.L NLrNLERICAL CODE 5'0 ,- ~ ..,:? --./ q i APPROVAL DATE. 10-15-68 PERMIT NO APPROVEDBY 3~-~---~. /( Executive Secretary DATE TITLE. . rvetion Committee DIRECTIONAL SURVEY REQUIRED /YES [] NO 36 ! 31 6 975' I 6 ~2] 7 LEG N-°. LAT. 61° 04' 36.38" LONG.150° 56' 5§.63" Y= 2,586~75 I X= 331,995 FROM N.W. COR. 1,250' SOUTH ~ 975' EAST. _-~; 0/3 / 2 SCALE I": 1,000' LEG Kg. 4 LEG N°. 2 LAT. 61° 04' 36.89" LAT. 61° 04' 35.83" LONG. 150° 56' 54.25" LONG. 150° 56' 54,77" Y= 2~586~781 Y= 2,586,674 X=. 332,063 X= 332,036 FROM KW. COR. FROM N.W. COR. 1,198' SOUTH & 1,305' SOUTH 8~ 1,043' EAST. ' 1,018' EAST. t'--~,12N ,liN 6 5 7 8 LEG NE $ LAT. 61u 04' 36.34" LONG. 150° 56' 53.39" Y= 2,586,72 4 X= 332~105 FROM N.W. COR. 1,254' SOUTH 8~ 1,085' EAST. NOTE: Plat amended 7AUG.68' to show revised leg numbering. CERTIFICATE OF SURVEYOR ! hereby certify that I am properly registered and licensed to practice land surveying in the State of Alaska and that this plat represents a location survey made by me or under my supervision and that all dimensions and other details are correct. SURVEYOR ~/' NOTE The location of the platform legs was accomplished by using triangulation stations BELUGA,TERRACE,and TYONEK which are all U.S.C.I~ G.S. stations. AIl coordinates are Alaska State Planes Zone 4. ~ PLAt'" 0 F ....... NORTH COOK I NIn,.E,,I'UNIT PLATFORM A FOR PHIL'LIPS. PETROLEUM· CO . SCALEi I"= I000' · Land I~ H~drographic FB. 11374 PP. !1-15 Surveyors I l¢'c: - 2602 W' NORTHERNL lo HTS BLVD' DRW'N. CHKD. JHG. il374 SPENARD, 80X4-0~1 ALASKA PROPOSED B.H.L. .~ N.C.I. Un. No. A-i ' ('89' FEL & 2575'FSE ef $ee,$612N-IOW'I, Mo) 51 l',, 6 18 DRWN. N. d. Powlll i :52 I PROPOSED BHL N,C,I, Un, No, A-2 (492.5'FN1. 8~ 264.~'FEL of $1~.~-IIN-~W) 5 l .... 11 . N GRID PHILLIPS PETROLEUM COMPANY 515 "D" STREET ANCHORAGE ~ALASKA PLAT OF NORTH COOK INLET UNIT PLATFORM '~" ISCAi.'E: ..... P?: .-?-,~e [ [ [ [ [ [ [ [ [[ i[ [ [ i[ f [ PHILLIPS PETROLEUM COMPANY 515 "D' STREET ANCHORAGE ALASKA NORTH COOK. INLET. · , flail PLATFORM.,-, COOK,INLET] ALASKA 'NOTE; 'Using PLATFORM NOP, TH~ Slot No, I will be thel furthest platform North slot in platform North-J west quadrant of any legi Slots will be numbcred] / I thru 8 in o counter-clock-wise..direction, ~LATFORM LOC'AT'ION: Se'¢.'6-11N-gW [DATE: AUC;U~,T 71 19. G8 ;~ 'DRWN. N.d. Pow. It [ NOT TO $(,~I"'E "~j HOOK, UP FOR DOUBLE PREVENTERS SERIES 1500 N,C.I.U. PLATFORM · i,_ --Si · e ~,, .~,~,~s ,~oo v,,.,,~_ I ' - ' G 2" SERIES 1500. VALVE · ~__-~ ~. '. ~ SERIES 1500 STEEL TEE _1 b ~~~,,= .~o~. ¢~,-;~~ _ ~ ~,, s~,~s ,~ o o ~ ~,, ~,~ ,~oo LL UP ~Ii~~,F;%WJ~ SPOOL ,~~~~ ' LINE ~$ ~r~'c~ L~ ~ ~ ' - I ~5oo .~~.,~~RAM-T'hPE BOP SERIES 15OO ,' ' (P~PE RA CROSS SERIES 1500 POSITIVE CHOKE SERIES 1500 ADJUSTABILE CHOKE PHILLIPS PETROLEUM CO,',,,~ANY ~ PRODUCTION DEPARTMENT 5000 PSl WORKING BLOWOUT PR[~VEN'FER HOOK-UP · · ~,~0~,: Domb]_e 2z~e~re~f, ez-s Az~e usect ~ ~ge~ side ou~e~s ¢o~ o~oke ~i¢o1~ (SERIES 1500 FLANGES OR BETTER) -, REV. 3/I~/GS SCHEDULE E Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information'of this nature is accumulated at the end of the file under APPENDIX, .. N° special'effort has been made to chronologically organize this category of information. Memow Multi-Finger Caliper Log Results Summary Company: PHILLIPS Well: Log Date: May 11, 2002 Field: Log No.: 4680 State: Run No.: I APl No.: Pipe1 Desc.: 4.5" 12.6 lb. J-55 Top Log Intvll .: Pipe1 Use: Tubing Bot. Log Intvll.: Inspection Type' NCIU A-2 North Cook Inlet Unit Alaska N/A 4,383 Ft. (MD) 6,620 Ft. (MD) Corrosive & Mechanical Damage Inspection COMMENTS - This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages. The caliper recordings indicate that the interval of 4.5" tubing logged is in good to poor condition. A hole is recorded in joint 197. The caliper recordings indicate a 27% wall penetration in joint 180. Penetrations of 20% and 24% are recorded in joints 157 and 154. No other significant penetrations (>16%) are recorded throughout the remainder of the interval logged. Recorded damage appears in the forms of General Corrosion with areas of deeper Isolated Pitting. No areas of significant cross-sectional wall loss are recorded throughout the logged interval. Deposits restrict the minimum measured ID to 3.64" in joint 172. The distribution of penetrations is illustrated in the Body Region Analysis Page of this report. The field engineer reported erratic slick line pulling speed and many tool hang-ups dudng the log run. This resulted in several intervals of minimal recorded data where the tool experfenced excessive acceleration upon pulling loose from the hang ups. The joint count numbering is an approximation based on the average joint length and the log start depth. TUBING - MAXIMUM RECORDED WALL PENETRATIONS · Hole (100%) Jt. 197 @ 6,102 Ft. (MD) Corrosion (27%) Jt. 180 @ 5,588 Ft. (MD) Isolated Pitting (24%) Jt. 154 @ 4,735 Ft. (MD) Isolated Pitting (20%) Jt. 157 @ 4,841 Ft. (MD) No other significant penetrations (>16%) are recorded throughout the interval logged. TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS · No areas of significant cross-sectional metal loss (> 14%) are recorded throughout the interval logged. TUBING - MAXIMUM RECORDED ID RESTRICTIONS · Deposits Min. I.D. = 3.64" Jt. 172 @ 5,311 Ft. (MD) Deposits Min. I.D. = 3.64" Jt. 150 @ 4,535 Ft. (MD) Deposits Min. I.D. = 3.65" Jt. 152 @ 4,629 Ft. (MD) Deposits Min. I.D. = 3.67" Jt. 161 @ 4,949 Ft. (MD) Deposits Min. I.D. = 3.68" Jt. 154 @ 4,717 Ft. (MD) Field Engineer' S. Adcock Analyst: M. Lawrence Witness: N/A ProActive Diagnostic Services, [nc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (28:[) 565-1369 E-mail' PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 PDS Report Overview Body Region Analysis Well: NCIU A-2 Survey Date: May 11,2002 Field: North Cook Inlet Unit Tool Ty'pe: MFC40 No. 00432 Company: Phillips Tool Size: 2,75 Country: USA No. of Fingers: 40 Analyst: M. Lawrence Tubing: Nora,OD Weight G~ade & Th(ead Nora. ID Nom. Upset Upper Ion. Lower Ion. 4.5 ins 12.6 ~B~ ~-55 3.958 ins 4.5 ins 1.2 ins 1.2 ins Penetration a~d Metal Less (% wall) ~ penetration body ~'2: metal loss body 80 60 40 20 0 0 tO 1 to 10 tO 20 to 40 to over 1% 10% 20% 40% 85% 85°/,1 Number of joints analysed (total = 98) pene. 26 47 22 2 0 1 76 2 I I 0 0 0 Damage Config=ral'io. ( body ) 2O 10 Number of ioints damaged (total = 22} 2O 1 0 0 1 Damage Profile (% wail) penetration body meta{ loss body 0 50 100 1,45 152 164 177 ~ 96 Bottom of Survey = 21 } Analysis Ow!tv ew page 2 Field: Compally: Country: PDS Caliper Minimum Diameter Profile NCIU A 2 Survey Date:May 11, 2002 North Cook Inlel Unil Tool: MF(40 No, 00432 Phillit)s Tool Size: 2.75 inches USA Tubing I.D.:3.958 inches Minimum Measured Diameters (In.) 275 285 295 305 315 325 t35 345 355 565 3.75 385 395 i 15430 1680o '~. PDS REP~ JOINT TABULATION SHEET Pipe: 4.5 ins 12.(, ppf J 55 Well: NCIU Wall thiekness: Body - 0,271 ins Upset - 0.271 ins Field: North Cook Inlet Unit Nominal ID: 3.958 ins Company: Phillips Country: USA Survey Date: May 11,2002 joint Penetration J~Vleta~ j Proiedion Mir~imum J i No. Upset Bd¢~Up BoclyI iLoss [Cping ~ody ID C ....... ents 145.1 inches inchesinches % ~ % inches [ inches inches ~6 ~- ~ .01~ 4 I 0 3~g5 kL Deposits. }46.1 0 0 0 0 0 3.81 X Nip 147 0 ~7 ~'~ ] 3.73 Shallow pitting. 148 0 B .0~_]. 10 10 i .1 ~ 3.77 Lt. Deposits. 149 0 [ 0 .03 I0 3 .05 .14 3.79 Lt. Deposits. 15B 0 ] B ........................................... .03 1 ~ 1 0 .25 3.64 Shal}ow pitting. Deposits. 150.1 0 0 0 0 0 0 0 3.81 SLDNG SLV (Q~)~ _ 150.2 0 0 0 0 0 0 0 3.99 NO GO SEAL 150.3 0 0 0 0 0 0 0 4.00 PACKER f50.4 0 0 B 0 0 0 0 4.27 MILL OUT EXT t 50.5B 0 .02 8 ] 0 .06 3,87 PUP I L Deposits, 150,6 0 0 .01 4 1 0 .04 3.90 PUP t51 0 0 ,03 12 1 0 .15 3.79 Shallow pitdng. Lt. Deposits. t 52 0 0 .03 13 2 ] 0 .29 3.65 Shallow pitting. Deposits, t52.I 0 0 0 0 0 ] 0 0 3.8~ StDNG SLV (Open} t52.2 0 0 0 0 0 0 0 3.99 NO GO SEAL [52.3 0 0 0 _ (_ )0 0 0 4.00 PACKER t52.4 0 0 0 0 0 0 0 4.27 MEL O_ U'[ EX~ [52,5 ~ 0 0 .03 ~ 1 1 0 .08 3.88 PUP LL Deposits, 152.6 ~ 0 0 ,0'-~- 3 1 0 B 3.94 PUP 153 [ 0 0 .B3 12 1 0 .11]--3.72 Shallow pitting. Lt, De~osiU. 153.1 0 ] 0 B 0 0 0 0 3.8} SLDNG S[V t54 0J ,04,07 24 1 .17 .26 3.68 Isolated pJ~Sng, Deposit~ 154.1 0 0 B 0 0 0 0 3.99 NO GO SEAL ~ 54.20 0 B 0 0 0 0 4.00 PACKER }54.3 0 0 0 0 0 0 0 4,27 MILL OUT EXT 155 0 0 .02 7 1 .07- .08 3.85 LL Deposits. 156 0 0 .02 7 I 0 .14 3.77 LL DeBt, its. 157 0 0 .05 20 2 0 .1_~_ 3.79 Isolated pitting. Lt. Deposhs. ___. t 58 0 0 .B2 B t 0 .1 ~ :.~.76Lt. Deposiu. 159 0 0 .03 10 1 .06 .15 3.75 Lt. Deposits. 160 0 0 .Og 1_~ I .06 .I~ 3.79 Jr. Deposhs. 161 0 0 .B3 12 3 0 .23 3.67 Shallow p~lt~n~. Deposits. i62 0 0 .02 9 2 0 .16.._ 3.74 Lt. Deposhs. 162. l0 0 0 0 0 0 0 3.99 NO GO SEAL 162.2 0 0 0 0 0 0 0 4.00 PACKER 162.3 B B 0 0 0 0 0 4.27 MILL OUT EXP ~63 0 0 .03 12 2 .07 .15 ..... :L78 Shallow pitting. Lt. Deposits. 164 0 .03 3)3..._ 13 t .19.17 3.70 ShaJlowpitting. Lt.Q~p~sits. 164.1 0 0 0 0 0 0 0_ 3.81 SLDNG SLV (Open) 165 0 0 .03 11 2 .08.20 3.74 Deposits. 165.1 0 0 0 0 0 0 0 3.99 NO GO SEAL ~s.2 0 0 0 o 0 o 0 4.0B P~CKER ]66 0 0 .02 8 2 0 .14 3.79 JEt. DeposiU. 167 0 ()___ .04 16 2 .08.17 3.75 [ Shallow ~tdng. Lt. Deposits. ~ ........ .02 [ 9 2 .0E_ ._.j. 4 3.79 [ L~. Deposits. ---- penetration body metal loss body (% ',,,,,all) 0 50 100 Pipe Tabulations page 1 PDS JOINT TABULATION SHEET~ Pipe: 4,5 ins t 2.6 ppf I 55 Well: NCIU A-2 Wall thickness: Body = 0.271 ins Upset = 0.271 ins Field: North Cool< Inlet Unit Nominal ID: 3.958 ins Company: Phillips Country: LJSA Stu~ey Date: May I 1, 2002 rjoint Penetration MetalProjection Minimum No. Upset Bd@Up Body loss Cplng Body ID Comments inchesinchesinches% % inches inches inches 170 0 0 .03 10 2 0 .11 3.80 It. Deposits. 171 t) 0 .03 10 2 0 .13 ~.78 lt. Deposits. 172 0 0 .02 9 1 0 .28 3.64 Deposits. 173 0 0 .04 13 3 0 .14 3.75 S h alloL~ )i~_g:... k!:.Deposits. 174 I 0 0 .03 10 2 0 .14 3,79 Lt. Deposits. 174.1J 0 0 B 0 0 0 I 0 3.99 NO GO SEAL 174.2 ] B B 0 0 B i 0 t) 4.00 PACKER 1~777~30 0 0 0 0 [ 0 0 4,27 Mill. OUT EXT 0 B .01 4 1 0 0 3.88 176 0 0 .01 3 1 0 0 3.87 177 B 0 .04 15 1 0 .04 3.88 Shallow pitting, 178 0 0 .t) 1 6 I 0 .B4 3.87 179 B 0 .02 7 1 0 .04 L88 179.1 0 0 0 0 0 0 0 3.8t SLDNG SLV (Closed) 180 0 .09 .07 27 4 0 .05 3.86 Corrosion. 181 () i) .02 9 1 () 0 3.87 182 0 0 .01 4 1 t)__ .07 3.84 Lt. Deposits. t83 B 0 ,02 8 1 0 .B5 3.87 Lt. Deposits. 184 B (~)_ .03 13 1 0 .06 3,84 Shallow pitti2~_g. Lt. Deposits. 185 0 B .02 7 2 0 .04 3.87 t 86 0 0 .02 8 1 0 .06 3.87 ~_c?~Z. 187 0 0 .01 4 1 0 0 3.87 188 0 0 __._ __ .013 2 0 .07 3.88 IL Deposils. 189 ] B 0 ,04 15 1 0 .06 3.86 Shallow pitting. Lt. Deposits..__..__ 19~4 0 0 .02 8 2 0 .OB 3.84 191 ] B 0 .03 13 I B __.05 3.86 Shallow pitting. Lt. Deposits. __ 192 0 0 .014 I 0 .06 3.88 Lt. p_2posits. 193 0 0 .02__.:7_ .... 1_ 0 .08 3.82 Lt. Deposits. 194 0 0 ____ .028 1 0 .07 3.86 Lt, Deposits. 195 0 0 .028 1 0 .06 3.B6 Lt. Deposits. t'~ 0 0 ____:.(_) 1 2 1 0 , t 6 3.77 LL Deposits. ~.97 0 0 .30 I00 14 0 .B_ 8 3.84 HOLE! [ 198 0 0 .02 9 1 0 0 3.88 t99 0 0 .03 10 I 0 0 .__3.88 ~200 0 0 .B2 8 1 0 0 3,88 1201 0 0 .02 9 1 0 .03 3.87 [ 202 B 0-" .B3 13 2 0 .05 3.85 Shallow 203 0 0 .02 8 I 0 .04 3~86 204 0 0 .01 4 I t) .()33.88 205 t) 0 __j_._. .03 t0 1 .06 .04 3.88 ,206 0 0 .01 5 t (_)____.B5 3.87 207 0 0 .029 1 0 0 ...... 3.88 · 208 0 0 .03 1 t I 0 .04 3.86 0 0 .01 5 0 .03 3.87 ~ 211~] 0 0 .03 11 0 .06 3.86 Shalk);v ~ittiq'~'~Lt. Det)osits. [ 212 I 0 () .02 8 0 .09 3.83 ti, Deposits~ penetration body metal loss body Damage Profile (% wall) 50 100 Pipe Tabulations page 2 Damage classification scheme Penetration / projection class, in order of damage severity Hole - penetration exceeds 85% of nominal wall thickness Ring - damage area exceeds 65% of circumference, but depth range does not exceed I * pipe ID Line - damage depth range exceeds 5 * pipe ID, but extends less than 20% of circumference. General - damage depth range exceeds 1 * pipe IDand/or extends more than 20% of circumference. Isolated - damage depth range does not exceed 5 * pipe ID or extend more than 20% of circumference. Damage reporting threshold -- 30 thou inches deviation in body, 50 thou in coupling. Modal line length -- 0.305 feet. Pipe Tabulations 3 I I ! I I ) ! I PDS Report Cross Sections Well: NCIU A-2 Field: North Cook Inlet Unit Company: Phillips Country: USA Tubing: 4.5 ins 12.6 ppf J-55 Survey Date: May 11, 2002 Tool Type: MFC40 No. 00432 Tool Size: 2.75 No. of Fingers: 40 Analyst: M. Lawrence Cross Section for Joint Tool speed = 58 Nominal ID = 3,958 Nominal OD = 4.500 Remaining wall area = 86 % Tool deviation = 64 ° 197 at depth 6102.62 ft Finger 3 Penetration = 0.298 ins Hole due to Corrosion 0.30 ins = 100% Wall Penetration HIGH SIDE = UP Cross Sections page 1 I ! I ) ! i ! ) i ! ! ! ! ) I ! I ) J Well: NCIU A-2 Field: North Cook Inlet Unit Company: Phillips Country: USA Tubing: , 4.5 ins 12.6 ppf J-$$ PDS Report Cross Sections Survey Date: May 11, 2002 Tool Type: MFC40 No. 00432 Tool Size: 2.75 No. of Fingers: 40 Analyst: M. Lawrence Cross Section for Joint Tool speed = 76 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 95 % Tool deviation = 75 ° 180 at depth 5587.58 ft Finger 14 Penetration = 0.088 ins Corrosion 0.09 ins = 27% Wall Penetration HIGH SIDE = UP Cross Sections page 2 ) ) ! J J J J J J J J ! J ! ! ) ! ) PDS Report Cross Sections Well: NCIU A-2 Field: North Cook Inlet Unit Company: Phillips Country: USA Tubing: 4.5 ins 12.6 ppf J-55 Survey Date: May 11, 2002 Tool Type: MFC40 No. 00432 Tool Size: 2.75 No. of Fingers: 40 Analyst: M. Lawrence Cross Section for Joint 1 72 Tool speed = 70 Nominal ID -- 3.958 Nominal OD = 4.500 Remaining wall area ~- 99 % Tool deviation: 78 ° at depth 5310.66 ft Finger 18 Projection = -0.278 ins Deposits Minimum I.D.: 3.64 ins HIGH SIDE = UP Cross Sections page 3 ) I I I ) I I :l I ! I I I I I I ! PDS REPORT JOINT TALLY SHEET Pipe: 4.5 ins 12,6 ppf J-55 Wall thickness: Body ~- 0.271 ins Upset ~- 0.271 ins Nominal ID: 3.958 ins Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches 145.1 4373,52 6.40 3.813 3.813 3.958 4.500 )brassy 145.2 4379.92 8.51 3.990 3.990 3.958 4,500 )acker 146 4388.43 3,1,07 3.945 3.943 3.958 4.500 ,!46,~,1, ,4,4,1,9.50 ,2.77 3.813 3.813 3~813 , , 4.500 (,,nip 147 4422.27 31.13 3,943 3.940 3.958 4.500 148 4453.40 30.14 3.946 3,940 3,958 4,500 149 4483.54 31.00 3.943 3.939 3.958 4.500 150 4514,54 25.92 3.948 3.9,35 3.958 4,500 150,1 4540,46 7.32 3,813 3,813 3,813 4,500 ildng sly 150.2 4547.78 2.84 3.990 3.990 3.990 4.500 3o go seal 150.3 4550.,62 4.39 4.000 4,000 4.000 ,4.500 ~acker 150.4 4555.01 6.27 4.270 4.270 4.270 4.500 ~nill out ext 150.5 4561.28 11.19 3.942 3,945 3.958 4.500 ~up 150.6 4572,47 8.54 3.939 3.946 3.958 4.500 3up 151 4581.01 27.09 3.951 3.943 3,958 4.500 !52 4608.10 32.07 3.942 3.933 3.958 4,500 152.1 4640.17 6.90 3.813 3.813 3.813 4.500 ~ldng slv 152,2 4647.07 2.74 3.990 3.990 3.990 4.500 mo go seal 152.3 4649.81 3,57, 4.000 4.000 4,000 4.500 )acker 152.4 4653.38 7.97 4.270 4,270 4.270 4.500 mill out ext 152.5 4661.35 6.96 3.962 3.966 3.958 4.500 pup 152.6 4668.31 8.09 3.967 3,975 3.958 4.500 pup 153 4676.40 29.66 3.941 3.937 3.958 4.500 153.1 4706.06 6.05 3.813 3.813 3.813 4.500 sldngslv 154 4712.11 24.16 3.947 3.941 3.958 4.500 154.1 4736.27 6.87 3.990 3.990 3.990 4.500 no go seal 154.2 4743.14 3.05 4.000 4.000 4.000 4.500 ~acker 154.3 4746.19 6.64 4.270 4.270 4.270 4.500 hill out ext 155 4752.83 29.79 3.948 3.943 3,958 4.500 156 4782.62 31.40 3.944 3.939 3.958 4.500 157 4814.02 27.38 3.945 3.941 3.958 4.500 158 4841.40 36.23 3.942 3.937 3.958 4.500 159 4877.63 28.44 3.947 3.941 3.958 4.500 160 4906.07 27.94 3.943 3.936 3.958 4.500 161 4934.01 27.57 3.942 3.935 3.958 4.500 Well: Field: Company: Country: Survey Date: NCIU A-2 North Cook Inlet Unit Phillips USA May 11, 2002 Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches 162 4961.58 33.03 3.950 3,944 3.958 4.500 162.1 4994.61 2.58 3.990 3.990 3.990 4.500 no go seal 162.2 4997.19 3.19 4.000 4.000 4.000 4.500 ')acker 162.3 5000.38 ,6.36 4.270 4.270 4.27'0 4.500 'hill OUt ext 163 5006.74 31.24 3.945 3.938 3.958 4.500 164,, 5037.98 24.28 3.943 3,938 3.958 4.500 164.1 5062.26 9.48 3.813 3.813 3.813 4.500 ~ldng slv ,165 ,, 507!.,7'4 29.59 3.948 3.944, 3.958 4.500 ,,, 165.t 5101.33 4.13 3.990 3,990 3.990 4.500 ~o go seal 165.2 5105.46 3.50 4.000 4,000 4.000 4.500 :~acker 165.3 5108,96 3.27 , ,4.270 4.270 4.270 4.500 ~ill outext 166 5112.23 31.41 3.945 3,941 3.958 4,500 167 5143.64 29.59 3.946 3.940 3.958 4.500 168 5173.23 31.47 3.938 3.937 3.958 4.500 169 5204.70 27.38 3.944 3.942 3.958 4.500 170 5232.08 28.66 3.940 3.939 3,958 4.500 i 71 5260.74 32.53 3.949 3.943 3.958 4.500 172 5293.27 29.12 3.951 3.945 3.958 4.500 173 5322.39 29.49 3.947 3.940 3.958 4.500 174 5351.88 32.20 3.951 3.943 3.958 4.500 174.1 5384.08 2.10 3.990 3.990 3.990 4,500 no go seal 174.2 5386.18 4.03 4,000 4.000 4.000 4.500 )acker 174.3 5390.21 7.53 4.270 4.270 4.270 4.500 :Hill out ext 175 5397.74 23.85 3.938 3.938 3.958 4.500 176 5421.59 37.64 3.935 3,931 3.958 4.500 177 5459.23 28.90 3.939 3.938 3.958 4.500 178 5488.13 32.19 3.932 3.929 3.958 4.500 179 5520.32 30.76 3.935 3.935 3.958 4.500 179.1 5551.08 5,28 3.813 3.813 3,813 4.500 ~ldng siv 180 5556.36 31,.47 3.931 3.930 3.958 4.500 181 5587.83 32.83 3.926 3.927 3.958 4.500 182 5620.66 24.02 3.931 3.930 3.958 4.500 183 5644.68 38.56 3.938 3.936 3.958 4.500 184 5683.24 31.05 3.931 3.929 3.958 4.500 185 5714.29 31.24 3.935 3.933 3.958 4.500 Joint Tally page 1 ] '} I ! ! ] ! ! PDS REPORT JOINT TALLY SHEET Pipe: 4.5 ins 12.6 ppf J-55 Wall thickness: Body = 0.271 ins Upset = 0.271 ins Nominal ID: 3.958 ins Joint Depth Length Modal Mean Nominal ~lominal Type No. ID ID ID OD feet feet inches inches inches inches 1.86 5745.53. 25.48 3.938 3.939 3.958 4.500 187 5771.01 35.38 3.933 3.931 3.958 4.500 188 5806.39 26.34 .3.937 3.933 .. 3.958 4.500 189 5832.73 37.26 3.937 3.935 3.958 4.500 ............ 190 5869.99 31.25 3.930 3.925 3.958 4.500 191 5901.24 31.33 3.934 3.929 3.958 4.500 192 5932.57 29.99 3.933 3.931 3.958 4.500 193 5962.56 31.37 3.931 3.928 3.958 4.500 194 5993.93 31.60 3.937 3.935 3.958 4.500 195 6025.53 33.05 3.932 3.927 3.958 4.500 1196 6058.58 30.72 3.933 3.930 3.958 4.500 ""i' 9~' "6~89.30 31.33 3.937 3.935' 3.958 4.500 198 6120.63 30.55 3.937 3.935 3.958 4.500 199 6151.18 32.10 3.932 3.93.1 3.958 4.500 200 6183.28 32.31 3.938 3.935 3.958 4.500 201 6215.59 26.99 3.932 3.932 3.958 4.500 202 6242.58 35.75 3.923 3.922 3.958 4.500 203 6278.33 30.23 3.938 3.936 3.958 4.500 204 6308.56 31.18 3.927 3.926 3.958 4.500 205 6339.74 26.91 3.939 3.939 3.958 4.500 206 6366.65 36.90 3.933 3.928 3.958 4.500 207 6403.55 31.73 3.928 3.926 3.958 4.500 208 6435.28 31.08 3.932 3.928 3.958 4.500 209 6466.36 31.28 3.937 3.933 3.958 4.500 210 6497.64 32.93 3.936 3.933 3.958 4.500 ....211 6530.57 30.20 3.933 3.931 3.958 4.500 212 6560.77 33.94 3.930 3.924 3.958 4.500 213 6594.71 N/^ 3.929 3.926 3.958 4.500 Well: Field: Company: Country: Survey Date: NCIU A-2 North Cook Inlet Unit Phillips USA May 11, 2002 Joint Depth Length Modal Mean Nominal Nominal rype No. ID ID ID OD feet feet inches inches inches inches , ,, ................... ...... Joint Tally page 2